Deepwater Horizon Oil Spill:
Selected Issues for Congress
Curry L. Hagerty, Coordinator
Specialist in Energy and Natural Resources Policy
Jonathan L. Ramseur, Coordinator
Specialist in Environmental Policy
July 15, 2010
Congressional Research Service
7-5700
www.crs.gov
R41262
CRS Report for Congress
P
repared for Members and Committees of Congress
Deepwater Horizon Oil Spill: Selected Issues for Congress
Summary
On April 20, 2010, an explosion and fire occurred on the Deepwater Horizon drilling rig in the
Gulf of Mexico. This resulted in 11 worker fatalities, a massive oil release, and a national
response effort in the Gulf of Mexico region by the federal and state governments as well as BP.
Based on estimates from the Flow Rate Technical Group, which is led by the U.S. Geological
Survey, the 2010 Gulf spill has become the largest oil spill in U.S. waters. The oil spill has
damaged natural resources and has had regional economic impacts. In addition, questions have
been raised as to whether offshore regulation of oil exploration has kept pace with the
increasingly complex technologies needed to explore and develop deeper waters.
Crude oil has been washing into marshes and estuaries and onto beaches in Louisiana,
Mississippi, and Alabama. Oil has killed wildlife, and efforts are underway to save oil-coated
birds. The most immediate economic impact of the oil spill has been on the Gulf fishing industry:
commercial and recreational fishing have faced extensive prohibitions within the federal waters
of the Gulf exclusive economic zone. The fishing industry, including seafood processing and
related wholesale and retail businesses, supports over 200,000 jobs with related economic activity
of $5.5 billion. Other immediate economic impacts include a decline in tourism. On the other
hand, jobs related to cleanup activities could mitigate some of the losses in the fishing and
tourism industry.
The Bureau of Ocean Energy Management, Regulation, and Enforcement (BOEMRE), formerly
known as the Minerals Management Service (MMS), and the U.S. Coast Guard are the primary
regulators of drilling activity. The Environmental Protection Agency (EPA) has multiple
responsibilities, with a representative serving as the vice-chair of the National Response Team
and Regional Response Teams. The Federal Emergency Management Administration (FEMA)
has responsibilities with respect to the economic impacts of the spill; its role so far has been
primarily that of an observer, but that may change once the scope of impacts can be better
understood.
BOEMRE/MMS is also the lead regulatory authority for offshore oil and gas leasing, including
collection of royalty payments. Its regulations generally require that a company with leasing
obligations demonstrate that proposed oil and gas activity conforms to federal laws and
regulations, is safe, prevents waste, does not unreasonably interfere with other uses of the outer
continental shelf, and does not cause impermissible harm or damage to the human, marine, or
coastal environments. On May 13, 2010, the Department of the Interior announced that Secretary
Ken Salazar had initiated the process of reorganizing the MMS administratively to separate the
financial and regulatory missions of the agency. The Coast Guard generally overseas the safety of
systems at the platform level of a mobile offshore drilling unit.
Several issues for Congress have emerged as a result of the Deepwater Horizon incident. What
lessons should be drawn from the incident? What technological and regulatory changes may be
needed to meet risks peculiar to drilling in deeper water? How should Congress distribute costs
associated with a catastrophic oil spill? What interventions may be necessary to ensure recovery
of Gulf resources and amenities? What does the Deepwater Horizon incident imply for national
energy policy, and the trade-offs between energy needs, risks of deepwater drilling, and protection
of natural resources and amenities? This report provides an overview of selected issues related to
the Deepwater Horizon incident and is not intended to be comprehensive. It will be updated to
reflect emerging issues.
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Deepwater Horizon Oil Spill: Selected Issues for Congress
Contents
Introduction ................................................................................................................................ 1
Setting: Oil and Gas Recovery in the Gulf of Mexico .................................................................. 2
Offshore Oil and Gas Drilling Technology............................................................................. 2
Methane Hydrates in the Gulf of Mexico............................................................................... 4
Weather and Ocean Currents in the Gulf of Mexico ............................................................... 5
Biological Resources of the Gulf of Mexico .......................................................................... 6
Federal Statutory Framework ...................................................................................................... 6
OCS Leasing......................................................................................................................... 7
Oil Spill Response ................................................................................................................ 7
National Contingency Plan.............................................................................................. 8
Role of the Secretary of Homeland Security .................................................................... 9
National Response Framework........................................................................................ 9
Oil Spill Liability ................................................................................................................ 10
Limits (or Caps) to Liability.......................................................................................... 11
Loss of Liability Limit .................................................................................................. 11
Oil Spill Liability Trust Fund ........................................................................................ 12
OPA Compensation and Claims Process .............................................................................. 12
Federal Regulatory Framework ................................................................................................. 13
Bureau of Ocean Energy Management, Regulation, and Enforcement (BOEMRE,
Formerly MMS)............................................................................................................... 14
Wells............................................................................................................................. 15
Platforms ...................................................................................................................... 15
Equipment and Facilities ............................................................................................... 16
Role of U.S. Coast Guard.................................................................................................... 16
The International Maritime Organization (IMO)............................................................ 17
Classification Societies ................................................................................................. 17
Oil Spill Response Issues .......................................................................................................... 18
Use of Dispersants .............................................................................................................. 18
Louisiana Protective Berm Project ...................................................................................... 20
Relief Wells ........................................................................................................................ 22
What Are Relief Wells? ................................................................................................. 22
Examples of Relief Wells Being Used to Stop Blowouts................................................ 23
Relief Well Policies....................................................................................................... 24
Issues for Further Consideration.................................................................................... 25
Response Vessels and the Jones Act..................................................................................... 27
Investigations and Commissions ............................................................................................... 27
Environmental and Economic Impacts ...................................................................................... 28
Environmental Impacts ....................................................................................................... 28
Natural Resource Damage Assessment and Compensation............................................. 29
Environmental Recovery............................................................................................... 30
Economic Impacts............................................................................................................... 30
Natural Resources and Related Economic Activity ........................................................ 30
Impact on Oil and Natural Gas Prices ............................................................................ 32
Possible Impacts on Shipping........................................................................................ 34
Labor Issues.............................................................................................................................. 34
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Deepwater Horizon Oil Spill: Selected Issues for Congress
Safety and Health of OCS Workers...................................................................................... 34
Oil and Gas Industry Safety Statistics.................................................................................. 35
Coast Guard Oversight of OCS Safety................................................................................. 37
Technical Competence .................................................................................................. 37
Regulatory Issues .......................................................................................................... 37
IMO Convention Issues................................................................................................. 38
DOI Initiative to Reorganize MMS............................................................................................ 39
Reorganization Authority of the Secretary of the Interior ..................................................... 39
Establishment of the Minerals Management Service ............................................................ 40
Redelegation of Minerals Management Service Functions ................................................... 40
Other Congressional Activity Related to Agency Reorganization ......................................... 42
Legislation Related to Agency Reorganization..................................................................... 43
FEMA Issues ............................................................................................................................ 43
Federal Duplication/Federal Coordination ........................................................................... 44
Exxon Valdez....................................................................................................................... 44
Recent Regional Disaster History........................................................................................ 45
Conclusion................................................................................................................................ 46
Figures
Figure 1. The Loop Current ......................................................................................................... 6
Figure 2. Dispersant Application in Gulf Oil Spill ..................................................................... 20
Figure 3. Image of Two Relief Wells Being Drilled by BP to Plug the Deepwater Horizon
Well ....................................................................................................................................... 23
Figure 4. Gulf of Mexico Fishery Closure ................................................................................. 31
Contacts
Author Contact Information ...................................................................................................... 47
Congressional Research Service
Deepwater Horizon Oil Spill: Selected Issues for Congress
Introduction
On April 20, 2010, the Deepwater Horizon oil drill rig, reportedly under contract to BP, the
leaseholder of the tract approximately 50 miles offshore of Louisiana, was nearing completion of
a deepwater oil well when an explosion occurred. An apparent equipment failure, perhaps of the
blowout protector, at the wellhead released oil and natural gas; explosions and fire on the oil rig
killed 11 of the crew, and the rig sank within days. Based on estimates from the Flow Rate
Technical Group, which is led by the U.S. Geological Survey,1 the 2010 Gulf spill has become the
largest oil spill in U.S. waters, eclipsing the 1989 Exxon Valdez spill several times over. Crude oil
has been washing into estuaries and onto beaches in Louisiana, Mississippi, and Alabama;
affected fishing and shrimping areas in the Gulf of Mexico have been closed.
The former Minerals Management Service (MMS), now known as the Bureau of Ocean Energy
Management, Regulation, and Enforcement (BOEMRE), in the Department of the Interior (DOI)
is responsible for leasing the tract to BP.2 (Because the name change is relatively recent, hereafter
in this report this agency will be referred to as BOEMRE/MMS.) The U.S. Coast Guard oversees
the fitness of the rig and efforts to control the leak. The Environmental Protection Agency (EPA)
has multiple responsibilities, with a representative serving as the vice-chair of the National
Response Team and Regional Response Teams. The Federal Emergency Management
Administration (FEMA) has responsibilities with respect to the economic impacts of the spill; its
role so far has been primarily that of an observer, but that may change once the scope of impacts
can be better understood. Information about the Deepwater Horizon rig, its drilling operations,
and the federal response to the oil spill is available from numerous sources, including
BOEMRE/MMS and the Coast Guard, the two agencies with lead federal roles in governing
response efforts. As the lessee of the area in which the offshore facility is located, BP is
responsible for capping the leak and paying for removal costs.
Issues such as worker safety, economic and environmental impacts, and oil and gas
leasing for exploration and development are the focus of congressional attention at this
time. The incident has triggered numerous congressional hearings, including those
investigating the causes of the blowout; impacts of the spill; liability for damages; and the
administrative process of leasing and regulatory requirements concerning health, safety,
and environmental protection in drilling.
Secretary Ken Salazar of DOI initiated changes in the administration of offshore oil
drilling by splitting MMS functions into three new bureaus, one to conduct leasing, one
to enforce safety and environmental requirements, and one to handle revenues. Congress
will be evaluating this reorganization and examining the adequacy and effectiveness of
statutes governing leasing and oil spills, including the Outer Continental Shelf Lands Act
of 1953, as amended (OCSLA), and the Oil Pollution Act of 1990 (OPA).
This report provides an initial overview of Deepwater Horizon-related issues for Congress, and
refers readers to in-depth CRS reports on specific issues. Congressional readers with questions
1 For up-to-date estimates of the spill rate, see the most recent press releases from the Department of Interior, at
http://www.doi.gov/news/index.cfm/.
2 Secretarial Order 3302, issued June 18, 2010, changed the name of the Minerals Management Service to the Bureau
of Ocean Energy Management, Regulation, and Enforcement (BOEMRE). The name change was effective
immediately.
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about an issue discussed in this report should contact the experts listed in CRS Report R40883,
Oil Spill in the Gulf of Mexico: CRS Experts.
Setting: Oil and Gas Recovery in the Gulf of Mexico
Sediments buried deep below the seafloor in the Gulf of Mexico host large quantities of oil and
gas that have been the target of exploration activities for decades. Most of the undiscovered oil
and gas on the U.S. outer continental shelf (OCS) is thought to occur in the Gulf, particularly in
the central and western regions. In fact, the central and western Gulf account for about 48% of the
undiscovered technically recoverable resource (UTRR)3 for oil and about 50% of the UTRR for
natural gas in the entire U.S. OCS, according to the Department of the Interior.4 (In comparison,
Alaska accounts for about 31% of the UTRR for oil and gas in the OCS.)
Recent attention has focused on oil and gas resources underlying deep water in the Gulf (i.e.,
deeper than 1,000 feet), because that is where the largest resource potential exists and where the
majority of OCS leases are held.5 Since 2006, there has been a 44% increase in proven deepwater
discoveries in the Gulf, even though most of the deepwater leases are yet undrilled. (For example,
272 of nearly 1,900 ultra-deepwater leases—those at a water depth greater than 5,000 feet—were
drilled between 1996 and 2007.) Deepwater and ultra-deepwater exploration and development
have been the focus of OCS oil and gas development in recent years, and the potential for new
and large discoveries in that part of the Gulf has been viewed as key to slowing or stopping the
decline in OCS oil and gas reserves. (For a more complete discussion of OCS oil and gas issues,
see CRS Report R40645, U.S. Offshore Oil and Gas Resources: Prospects and Processes, by
Marc Humphries, Robert Pirog, and Gene Whitney.)
Offshore Oil and Gas Drilling Technology6
In comparison with nearshore oil and gas activities, deepwater and ultra-deepwater exploration
and production require technologies that can withstand high pressures and low temperatures at the
seafloor, and require the operator to control the process remotely from a surface vessel thousands
of feet above the actual well. Seawater temperatures are lower in these waters (for example, at
5,000 feet deep in the Gulf, the seafloor water temperature is about 40o F, or 4.4o C); and
pressures are greater (at 5,000 feet deep the seafloor pressure is about 2,500 psi). Consequently,
equipment and operations at the seafloor are accessible only by remotely operated vehicles
(ROVs). Drilling technologies built to withstand the harsher conditions in deep water and ultra-
deep water are complicated, difficult to repair, and expensive. In addition, long lengths of pipe, or
marine “riser,” extending from the seafloor to the drill rig, are needed, requiring a large and
complex surface platform to conduct operations through the longer pipe. One of the most
common types of drilling platforms for deep water and ultra-deep water is a semisubmersible rig,
3 Undiscovered technically recoverable resources (UTRR) are estimates of the volume of oil or natural gas that are
likely to be recovered using currently available technologies without considering price. UTRR changes as available
technology changes, but not as price changes.
4 Statement of Steven C. Allred, DOI/MMS, January 25, 2007.
5 Thirty-five percent of active OCS leases are in water depths of less than 200 meters, while 51% of active OCS leases
are in water depths of 1,000 meters and deeper.
6 Prepared by Peter Folger, Specialist in Energy and Natural Resources Policy.
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which has an upper and lower hull. During the drilling operation, the lower hull is filled with
water, partially submerging the rig but leaving the upper hull floating above the drill site.7
Transocean’s Deepwater Horizon rig was a semisubmersible platform, kept in place above the
drill site by a dynamic positioning system (i.e., not permanently anchored to the seafloor) and
connected to the well by the marine riser.8
During drilling operations, the drill bit and drill pipe (or drill string) extend through the riser from
the drill platform and through a subsea drilling template—essentially a large metal box embedded
in the seafloor—into the marine sediments and rocks down to the hydrocarbon-bearing zone. A
special fluid called drilling mud (a mixture of water, clay, barite, and other materials) is circulated
down to the drill bit and back up to the drilling platform. The drilling mud, which has higher
viscosity and density than water, serves several purposes: it lubricates the drill bit, helps convey
rock cuttings from the drill bit back to the surface, and exerts a column of weight down the hole
to control pressure against a possible blowout. A blowout can occur if the subterranean pressure
encountered down the hole exceeds the pressure exerted by the weight of the drill assembly and
drilling mud. The Deepwater Horizon rig experienced a blowout on April 20, 2010, and the role
of the drilling fluid is under investigation.
Drilling a deepwater or ultra-deepwater well is a multi-step process. At different stages the drill
string is removed and steel casing is inserted into the wellbore, telescoping down from the
largest-diameter casing at the top of the well to the smallest diameter at the bottom. Casing
serves, among other things, to stabilize the wellbore, prevent the formation from caving in,
maintain control of fluid pressure, and prevent crossflow of fluids from one part of the formation
to another. The bottommost interval of casing, usually called the production casing, is inserted
through the interval in the formation containing hydrocarbons that the operator wishes to produce.
The casing is cemented in place over various intervals; cement is injected between the well casing
and the surrounding rock. In addition, cement may be injected into intervals of the casing itself
when the well is to be temporarily or permanently plugged.9 At the Deepwater Horizon well,
Halliburton (as a contractor for BP) had finished cementing the final production casing string
about 20 hours before the blowout on April 20, according to congressional testimony.10
As a last line of defense against a blowout, a blowout preventer (BOP) is installed at the seafloor
and connected to the marine riser. The BOP is essentially a system of valves designed to be closed
in the event of anomalous wellbore pressure (such pressure is sometimes referred to as a “kick”).
At the depth and pressures encountered by the Deepwater Horizon well, BOEMRE/MMS
regulations require at least four such valves, or rams, which must be remote-controlled and
hydraulically operated during offshore operations.11 During the Deepwater Horizon blowout, all
of the rams on the BOP failed to close properly.
7 For a more detailed description of drilling rigs, see http://www.naturalgas.org/naturalgas/extraction_offshore.asp.
8 For specifications about the Deepwater Horizon, see http://www.deepwater.com/fw/main/Deepwater-Horizon-
56C17.html?LayoutID=17.
9 For example, in the Deepwater Horizon well, casing intervals spanned nine different diameters, from 36-inch
diameter casing at the top of the well, to 7-inch diameter casing at the bottom, according to congressional testimony.
Also, the witness stated that there was no continuous cement column throughout the entire wellbore. Testimony by Tim
Probert, President, Global Business Lines and Chief Health, Safety, and Environmental Officer, Halliburton, hearing to
review current issues related to offshore oil and gas development, U.S. Congress, Senate Committee on Energy and
Natural Resources, 111th Cong., 2nd sess., May 11, 2010.
10 Testimony by Tim Probert, Halliburton, May 11, 2010.
11 30 C.F.R. § 250.442.
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BOPs can have backup systems that would attempt to engage the rams in case of loss of direct
communication to the drilling vessel at the surface. One type of backup system, referred to as a
“deadman switch,” is intended to operate automatically if communication to the surface is
disrupted. A second type of backup system, referred to as an “autoshear,” would automatically
activate one of the rams if the lower marine riser pipe disconnected. Another form of backup
system includes the use of remotely operated vehicles (ROVs), controlled from the surface, which
can operate control panels on the BOP itself at the seafloor. In the Deepwater Horizon incident,
the BOP was reportedly equipped with a deadman switch12 and an autoshear device, and ROVs
were used to attempt to activate the BOP after the blowout occurred. These systems appear to
have failed to fully engage the BOP.
Methane Hydrates in the Gulf of Mexico13
At the temperatures and pressures of deepwater and ultra-deepwater drilling in the Gulf of
Mexico, solid methane hydrates can occur. They constitute a potential natural gas resource as well
as a possible risk to exploration activities. In a methane hydrate, frozen water molecules form a
cage-like structure around molecules of methane, the primary component of natural gas. In 2007,
BOEMRE/MMS released an estimate of methane hydrate resources in the Gulf with a mean value
of 21,000 trillion cubic feet, although the report noted that the amount of hydrate commercially
recoverable using current technology is likely just a fraction of that resource.14 Methane hydrates
also present a significant hazard for drilling and production operations.15 Offshore drilling
operations that disturb methane hydrate-bearing sediments could fracture or disrupt the bottom
sediments and compromise the wellbore, pipelines, rig supports, and other equipment involved in
oil and gas production from the seafloor.16 Decreases in pressure and/or increases in temperature
can cause solid methane hydrate to dissociate and rapidly release large amounts of gas into the
wellbore during a drilling operation. (For a more detailed discussion of methane hydrates, see
CRS Report RS22990, Gas Hydrates: Resource and Hazard, by Peter Folger.)
Methane hydrates also have interfered with attempts to divert oil and gas from the Deepwater
Horizon blowout. When BP first attempted to lower a steel “cofferdam” over the leaking riser
pipe to intercept the oil and gas and divert it to the surface, methane hydrates formed and clogged
valves and piping leading to the surface. This occurred because methane gas from the wellbore
encountered cold seawater at 5,000 feet below the ocean surface, and methane converted from a
gas to solid methane hydrate. Methane hydrates are stable at that depth and temperature.
12 According to testimony by Steve Newman, President and CEO of Transocean Ltd., in response to questions during
the House Committee on Energy and Commerce, Subcommittee on Oversight and Investigations, Inquiry Into the
Deepwater Horizon Gulf Coast Oil Spill, hearing, 111th Cong., May 12, 2010.
13 Prepared by Peter Folger, Specialist in Energy and Natural Resources Policy.
14 U.S. Department of the Interior, Minerals Management Service, Resource Evaluation Division, “Preliminary
Evaluation of In-Place Gas Hydrate Resources: Gulf of Mexico Outer Continental Shelf,” OCS Report MMS 2008-004
(February 1, 2008), at http://www.mms.gov/revaldiv/GasHydrateFiles/MMS2008-004.pdf.
15 Timothy S. Collett and Scott R. Dallimore, “Detailed Analysis of Gas Hydrate Induced Drilling and Production
Hazards,” Proceedings of the Fourth International Conference on Gas Hydrates, Yokohama, Japan, April 19-23, 2002.
16 George J. Moridis and Michael B. Kowalsky, “Geomechanical Implications of Thermal Stresses on Hydrate-Bearing
Sediments,” Fire in the Ice, Methane Hydrate R&D Program newsletter, Winter 2006.
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Weather and Ocean Currents in the Gulf of Mexico17
Oil and gas operations in the Gulf of Mexico face severe weather hazards, namely hurricanes
during the summer and fall, that could disrupt operations and possibly cause leaks and spills from
drilling rigs and production platforms. For example, disruptions to oil and gas operations
occurred in 2005 during Hurricanes Katrina and Rita. As a result of the hurricanes, approximately
600,000 gallons were spilled from offshore oil platforms and associated pipelines in the Gulf.18
Hurricanes and the Gulf Oil Spill
A hurricane in the Gulf could have significant consequences for the oil spill’s impacts. The National Hurricane Center
(NHC) recently predicted an “active to extremely active” hurricane season in the Atlantic Ocean and Gulf. The
season began June 1 and extends through November 30 (a NOAA FAQ website notes that the season’s termination
date has gradually extended over time). Although past hurricanes have led to oil spills (e.g., Katrina in 2005), a
hurricane interacting with a pre-existing, significant oil spill would be an unprecedented event.
Movement of oil would depend greatly on the track, wind speed, and size of a hurricane, and other factors in the
evolution of the storm. The ultimate effects would be uncertain: some effects could be beneficial, others disastrous.
High winds and seas are expected to mix and weather the oil, which can help accelerate biodegradation processes
and dispersion. However, barrier islands that normally protect coastal wetlands from oil may be overtopped or
destroyed by winds and water. Furthermore, heavy winds and storm surges could push oil further inland into areas
that would not normally become oiled. Even after oil stops flowing from the Deepwater Horizon site, hurricane-
strength winds could stir up oil that has penetrated sediments, thus releasing oil and causing renewed impacts on
plants and wildlife.
In addition, as Hurricane Alex recently demonstrated, a hurricane could impede response efforts, requiring vessels
and personnel to abandon oil containment and recovery activities.
Sources: National Oceanic and Atmospheric Administration, “NOAA Expects Busy Atlantic Hurricane Season,”
NOAA News, May 27, 2010, at http://www.noaanews.noaa.gov/stories2010/20100527_hurricaneoutlook.html; NOAA
FAQ website, at http://www.aoml.noaa.gov/hrd/tcfaq/G1.html; NOAA, “NOAA’s Oil Spill Response, Hurricanes and
the Oil Spill,” May 27, 2010, at http://www.nhc.noaa.gov/pdf/hurricanes_oil_factsheet.pdf.
Winds and currents in the Gulf of Mexico also affect how oil will migrate away from the source
of the spill. One key oceanographic feature of the Gulf that could possibly transport an oil spill
into the Gulf Stream and up the Atlantic seaboard is called the Loop Current. The Loop Current is
a clockwise flow that joins together the Yucatan Current to the south with the Florida Current to
the east and flows through the Florida Straits. The Florida Current feeds into the Gulf Stream (see
Figure 1). The position of the Loop Current is not static but varies over time in the Gulf. Its
variability, combined with the location, size, and duration of an oil spill, will determine whether
the Loop Current could entrain the spilled oil and how much oil it could transport towards the
Florida Current. There is also the possibility that part of the Loop Current could break off and
form a separate, temporary “anticyclonic” (i.e., clockwise-moving) ring, which could keep
entrained oil circulating within the Gulf rather than connecting with the Florida Current.19 In
addition to the complicated flow pattern in the Loop Current, it is not clear how the Deepwater
Horizon oil spill—which not only occurs at the surface but extends from the seafloor through the
entire water column—might become entrained into the current and where it might migrate.
17 Prepared by Peter Folger, Specialist in Energy and Natural Resources Policy.
18 For more information about oil spills generally, see CRS Report RL33705, Oil Spills in U.S. Coastal Waters:
Background, Governance, and Issues for Congress, by Jonathan L. Ramseur.
19 E-mail from Robert H. Weisberg , Professor of Physical Oceanography, and colleagues, College of Marine Science,
University of South Florida, May 19, 2010.
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Figure 1. The Loop Current
Source: The Cooperative Institute for Marine and Atmospheric Studies, University of Miami Rosenstiel School,
modified by CRS, at http://oceancurrents.rsmas.miami.edu/atlantic/loop-current.html. Modified by CRS.
Notes: The arrows indicate the direction and magnitude of the current velocity. The Loop Current is shown by
black arrows surrounded by white.
Biological Resources of the Gulf of Mexico20
The Gulf of Mexico is home to productive, diverse, and valuable living natural resources. Some
major features of the U.S. Gulf include barrier islands, coastal wetlands, beaches, and coral reefs.
The combined coastline of these areas, including islands and inland areas, is 47,000 miles. The
coastal and ocean resources of the region provide commercial, recreational, ecological, historical,
educational, and aesthetic benefits to local communities and the nation. Coastal wetlands and
estuaries are nursery areas for many species, including those that support commercial fisheries,
such as shrimp, oysters, and blue crab, and those that support recreational fishing, such as
snappers, groupers, and drum. Attributes such as warm weather, white sand beaches, and seafood
restaurants make the Gulf a popular tourist destination. Major tourist-related businesses include
eating and drinking establishments, hotels and lodging, and amusement and recreation services.
Federal Statutory Framework21
The development of offshore oil, gas, and other mineral resources in the United States is subject
to a number of interrelated legal regimes, including international, federal, and state law.
20 Prepared by Harold F. Upton, Analyst in Natural Resources Policy.
21 Prepared by Adam Vann, Legislative Attorney.
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International law provides a framework for establishing national ownership or control of offshore
areas, and U.S. domestic law has, in substance, adopted these internationally recognized
principles. U.S. domestic law further defines U.S. ocean resource jurisdiction and ownership of
offshore minerals, dividing regulatory authority and ownership between the states and the federal
government based on the resource’s proximity to the shore. Below is a broad summary of the
framework.22
OCS Leasing
The basis for most federal regulation is the Outer Continental Shelf Lands Act (OCSLA),23 which
provides a system for offshore oil and gas exploration, leasing, and ultimate development. The
OCSLA establishes broad five-year planning periods for offshore leasing across the U.S. OCS as
well as other processes for leasing, development, and production. It also authorizes the
administration of health and safety requirements. All of these are administered by
BOEMRE/MMS.24 The OCSLA further provides for judicial review of agency actions alleged to
be in violation of federal law, including violations of the act itself, its implementing regulations,
and the terms of any permit or lease.25
Governance of offshore minerals and oil and gas development in the U.S. OCS is bifurcated
between state and federal law. States generally have primary authority in the 3-geographical-mile
area extending from their coasts pursuant to the Submerged Lands Act, with some exceptions.26
Laws governing oil and gas development in state waters vary significantly from state to state. The
federal government and its comprehensive regulatory regime govern those minerals located under
federal waters, which extend from the states’ offshore boundaries to at least 200 nautical miles
from the shore.
Oil Spill Response27
The Oil Pollution Act of 1990 (OPA, P.L. 101-380) and the Clean Water Act (CWA)28 are the
primary federal statutes governing the federal response to oil spills. As amended by OPA, Section
311(d)29 of the Clean Water Act authorized the President to develop a National Oil and Hazardous
Substances Pollution Contingency Plan (National Contingency Plan or NCP) to specify the
federal response actions and authorities related to an oil spill.30 Although the NCP is the operative
22 See CRS Report RL33404, Offshore Oil and Gas Development: Legal Framework, by Adam Vann.
23 43 U.S.C. § 1331 et seq.
24 MMS is in the process of reorganization into three bureaus (the Bureau of Ocean Energy Management, the Bureau of
Safety and Environmental Enforcement, and the Office of Natural Resource Revenue) pursuant to Order No. 3299
issued by Secretary of the Interior Ken Salazar on May 19, 2010.
25 43 U.S.C. § 1349.
26 U.S.C. § 1301(b).
27 Prepared by Jonathan L. Ramseur, Specialist in Environmental Policy.
28 33 U.S.C. §§ 1251-1387.
29 33 U.S.C. § 1321(d).
30 The first NCP was prepared in 1968 after U.S. policymakers observed the British government’s response to a 37-
million-gallon oil tanker spill (Torrey Canyon) off the coast of England. See EPA, “National Contingency Plan
Overview,” at http://www.epa.gov/emergencies/content/lawsregs/ncpover.htm.
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framework for oil spill response, other frameworks and authorities may play a role in the Gulf
spill response.
National Contingency Plan
The NCP establishes the National Response System (NRS), a multitiered and coordinated
national response strategy for addressing oil spills and releases of hazardous substances. The NCP
is codified in federal regulation at 40 C.F.R. Part 300. Subpart D specifically addresses response
to oil spills.31 Oil spill response actions required under the regulations of the NCP are binding and
enforceable, per the enforcement authorities of the OPA and the CWA.
Key components of the NRS include:
• National Response Team (NRT). This team is composed of representatives from
the federal departments and agencies assigned roles in responding to oil spills.
The U.S. Coast Guard chairs the NRT when a response is being mounted to a
spill in a coastal region. According to statements by the Administration, the
Secretary of the Department of Homeland Security, Janet Napolitano, is leading
the NRT in response to the Gulf spill.32
• Regional Response Teams (RRTs). RRTs are composed of regional
representatives of each NRT member agency, state governments, and local
governments. The Coast Guard leads the relevant RRT during responses to oil
spills in coastal zone. The Gulf spill involves Regions IV and VI.33
• Area Committees (ACs). These include qualified personnel from federal, state,
and local agencies. The primary function of each AC is to prepare an Area
Contingency Plan (ACP) for its designated area.
• On-Scene Coordinator (OSC). The OSC directs the response efforts and
coordinates all other efforts at the scene. In general, Coast Guard Captains of the
Port serve as OSCs for their particular area.34
As amended by OPA, the CWA provides the President with the authority to ensure that an oil spill
is effectively removed and actions are taken to prevent further discharge from the source.35
Executive Order 12777 (signed by President George H. W. Bush on October 18, 1991) delegated
response authority in the coastal zone to the Coast Guard OSC. The OSC is broadly empowered
to direct and coordinate all response and recovery activities of federal, state, local, and private
entities (including the responsible party), and will draw on resources available through the
appropriate ACPs and RRTs.36
31 Subpart E addresses response to hazardous substances, which is beyond the scope of this report. The Comprehensive
Environmental Response, Compensation, and Liability Act (CERCLA) is the statute that authorizes response to
hazardous substances. Combined, CERCLA, OPA, and the Clean Water Act provide the statutory authority for the
NCP as a whole.
32 See e.g., http://www.whitehouse.gov/deepwater-bp-oil-spill/.
33 Information and documents from these regions can be accessed via the NRT website at http://nrt.org/.
34 The corresponding role for spills in EPA’s jurisdiction is the Remedial Project Manager (RPM).
35 33 U.S.C. Section 1321(c).
36 The Oil Pollution Act of 1990 (P.L. 101-180) strengthened and clarified the federal government’s role in oil spill
response and cleanup. OPA Section 4201 amended Section 311(c) of the CWA to provide the President with authority
(continued...)
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In addition, the OSC determines the level of cleanup required. Although the federal government
must consult with designated trustees of natural resources and the governor of the state affected
by the spill, the decision that cleanup is completed and can be ended rests with the OSC. States
may require further work, but without the support of federal funding.37
Role of the Secretary of Homeland Security
The Secretary of the Department of Homeland Security (DHS) may be involved in an oil spill
response either through her/his lead role in the department in which the Coast Guard operates38 or
as the “principal federal official for domestic incident management.” This latter role was
established in Homeland Security Presidential Directive (HSPD) 5.39 The Secretary’s role will
depend on the nature and magnitude of the incident, but in most cases, the role will likely be
minimal.
For the Gulf oil spill, Secretary Napolitano is coordinating the federal response activities. A
specific role the Secretary has assumed in this regard is leading the NRT (discussed above). In
addition, on April 29, 2010, Secretary Napolitano classified the event as a Spill of National
Significance (SONS).40 This designation does not provide additional funding or authority, but
allows for the appointment of a National Incident Commander, whose role is to coordinate
strategic communications, national policy, and resource support, and to facilitate collaboration
with key parts of the federal, state and local governments. On the same day, Secretary Napolitano
named Coast Guard Admiral Thad Allen as the National Incident Commander (NIC).41
National Response Framework
The National Response Framework (NRF) is the federal government’s broader administrative
mechanism that is intended to coordinate the array of federal response plans.42 As such, the NRF
provides the administrative policies and guiding principles for a unified response from all levels
of government, and all sectors of communities, to all types of hazards through the combined
scope of the various federal response plans that it incorporates. However, the NRF itself is not an
(...continued)
(delegated to the USCG or EPA) to perform cleanup immediately using federal resources, monitor the response efforts
of the responsible party, or direct that party’s cleanup activities.
37 OPA Section 1011.
38 The Coast Guard was transferred to DHS in 2003.
39 The White House, Management of Domestic Incidents, Homeland Security Presidential Directive - 5, Washington,
DC, February 28, 2003, http://www.fas.org/irp/offdocs/nspd/hspd-5.html.
40 The predecessor to the National Response Framework—the National Response Plan (NRP)—contained a similar
sounding phrase, “Incident of National Significance.” This term caused significant confusion and was subsequently
eliminated in the NRF. For more information, see Department of Homeland Security, National Response Framework:
Frequently Asked Questions, at http://www.fema.gov/pdf/emergency/nrf/NRF_FAQ.pdf.
41 The authority for the SONS classification and NIC designation is found specifically in the NCP regulations at 40
CFR Section 300.323. However, this section authorizes the Commandant of the Coast Guard to classify a spill as a
SONS and to name a NIC. It is unclear whether the DHS Secretary was employing the authority provided by HSPD 5
to take these actions.
42 Authority for the creation of the NRF emanates from numerous sources. FEMA has described the NRF as being
guided by 15 “principal emergency authorities,” 48 other statutory authorities and regulations, 17 executive orders, and
20 presidential directives. U.S. Department of Homeland Security, Federal Emergency Management Agency, National
Response Framework: List of Authorities and References, January 2008.
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operational plan that dictates a step-by-step process for responding to a specific type of hazard,
nor is the NRF a binding and enforceable regulation like the NCP.43
The NRF contains 15 “emergency support functions” (ESFs), which coordinate the capabilities
and resources of various federal departments and agencies, state and local governments, and
certain private-sector and nongovernmental organizations. ESF #10—Oil and Hazardous
Materials Response—provides federal support in response to an actual or potential discharge
and/or uncontrolled release of oil or hazardous materials.44 In some cases, the ESFs point to
existing response frameworks and authorities. Such is the case with ESF #10, which identifies the
NCP as the operative structure for oil spill response. According to the DHS, ESF #10 has not been
activated in response to the Gulf spill.45 Regardless, the NCP is the operative framework, with or
without ESF #10 activation.
Oil Spill Liability46
OPA liability provisions apply to any discharge of oil (or threat of discharge) from a vessel (e.g.,
oil tanker) or facility (e.g., offshore oil rig)47 to navigable waters, adjoining shorelines, or the
exclusive economic zone of the United States (i.e., 200 nautical miles beyond the shore).48
Responsible parties, including owners/operators of vessels or facilities and/or lessees of offshore
facilities,49 are liable50 for (1) oil spill removal costs and (2) a range of other costs, including:
• injuries to natural resources (e.g., fish, animals, plants, and their habitats);
• loss of real personal property (and resultant economic losses);
• loss of subsistence use of natural resources;
• lost government revenues resulting from destruction of property or natural
resource injury;
• lost profits and earnings resulting from property loss or natural resource injury;
and
• costs of providing extra public services during or after spill response.51
43 For more on the NRF, see CRS Report RL34758, The National Response Framework: Overview and Possible Issues
for Congress, by Bruce R. Lindsay.
44 Emergency Support Function #10—Oil and Hazardous Materials Response Annex, available at
http://www.fema.gov/emergency/nrf/index.htm.
45 Per telephone conversation with DHS personnel (July 13, 2010).
46 Prepared by Jonathan L. Ramseur, Specialist in Environmental Policy, and James E. Nichols, Law Clerk.
47 The definition of “facility” is broadly worded and includes pipelines and motor vehicles. 33 U.S.C. 2701(9).
48 Under OPA, the terms “liable” and “liability” are “construed to be the standard of liability which obtains under
section 311 of the [Clean Water Act].” Courts have interpreted Section 311 of the Clean Water Act as imposing strict
liability on parties responsible for the discharge of oil or other hazardous substances into the waters of the United
States. See United States v. New York, 481 F.Supp. 4 (D.N.Y. 1979).
49 See 33 U.S.C. 2701(32).
50 Responsible parties have several defenses from liability (33 U.S.C. 2703): act of God, act of war, and act or omission
of certain third parties. These defenses are analogous to those of the Superfund statute (the Comprehensive
Environmental Response, Compensation, and Liability Act, or CERCLA, commonly known as Superfund, P.L. 96-510)
enacted in 1980 for releases of hazardous substances. See 42 U.S.C. 9607(b).
51 OPA Section 1002(b)(2).
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Compared to the pre-OPA liability framework, OPA significantly increased the range of covered
damages.52 Moreover, a responsible party is now liable (subject to the limits discussed below) for
all cleanup costs incurred not only by a government entity but also by a private party.53
Limits (or Caps) to Liability
With some exceptions (identified below), the liability of the responsible party is limited or capped
for each “incident.”54 Liability limits differ based on the source of the oil spill: some limits are
simple dollar amounts; in other cases liability is unlimited for cleanup costs, but there are limits
on other damages.
Mobile offshore drilling units (MODUs), like the Deepwater Horizon unit (owned by
Transocean), are first treated as tank vessels for purposes of liability caps. Based on the
Deepwater Horizon unit’s gross tonnage, its liability cap would be approximately $65 million
(per the National Pollution Funds Center).55 If removal and damage costs exceed this liability cap,
a MODU is deemed to be an offshore facility for the excess amount.56 Offshore facilities, like the
Gulf well leased to BP, have their liability capped at “all removal costs plus $75 million.”
The National Pollution Funds Center described the liability for this incident as follows:
The lessee of the area in which the offshore facility is located is clearly a responsible party for
the reported discharge below the surface from the well, an offshore facility. The OPA liability
limit, if it applies, is all removal costs plus $75 million. The owner of the MODU would also be a
tank vessel responsible party for any oil discharge on or above the surface of the water. The
MODU liability limit, if it applies, as a tank vessel, is approximately $65 million. If the OPA oil
removal costs and damages resulting from the discharge on or above the water exceed this
liability amount the MODU is treated as an offshore facility for the excess amount. In that case
the lessee of the area in which the offshore facility is located would be a liable responsible party
up to the offshore liability limit amount of all removal costs plus $75 million.57 (emphasis added
by CRS)
Loss of Liability Limit
Liability limits do not apply if the incident was “proximately caused” by “gross negligence or
willful misconduct” or “the violation of an applicable Federal safety, construction, or operating
regulation.” If one of these circumstances is determined to have occurred, liability would be
52 Congress recognized that “there is no comprehensive legislation in place that promptly and adequately compensates
those who suffer other types of economic loss as a result of an oil pollution incident.” U.S. Congress, House Committee
on Merchant Marine and Fisheries, report accompanying H.R. 1465, Oil Pollution Prevention, Removal, Liability, and
Compensation Act of 1989, H.Rept. 101-242, Part 2, 101st Cong., 1st sess., p. 31.
53 OPA Section 1002(b)(1).
54 “Incident” means any occurrence or series of occurrences having the same origin, involving one or more vessels,
facilities, or any combination thereof, resulting in the discharge or substantial threat of discharge of oil. 33 U.S.C.
2701(14).
55 See National Pollution Funds Center, “Oil Pollution Act Liabilities for Oil Removal Costs and Damages as They
May Apply to the Deepwater Horizon Incident” (undated).
56 33 U.S.C. 2704(b).
57 See National Pollution Funds Center, “Oil Pollution Act Liabilities for Oil Removal Costs and Damages as They
May Apply to the Deepwater Horizon Incident” (undated).
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unlimited. In addition, the responsible party must report the incident and cooperate with response
officials to take advantage of the liability caps. According to the National Pollution Funds Center,
liability limits are “not usually well defined until long after response,” and litigation may be
required to resolve the issue.58
Oil Spill Liability Trust Fund
Before the passage of OPA, federal funding for oil spill response was widely considered
inadequate,59 and damage recovery was difficult for private parties.60 To help address these issues,
Congress established the Oil Spill Liability Trust Fund (OSLTF). Although Congress created the
OSLTF in 1986,61 Congress did not authorize its use or provide its funding until after the Exxon
Valdez incident.
The OSLTF is a federally administered trust fund that may be used to pay costs related to federal
and state oil spill removal activities, costs incurred by federal, state, and Indian tribe trustees for
natural resource damage assessments, and unpaid damages claims.62 The fund is financed by a
per-barrel tax on crude oil received at U.S. refineries and on petroleum products imported into the
United States for consumption.63
OPA Compensation and Claims Process64
OPA established a compensation and claims process for removal costs and the costs/damages
identified above.65 In general, claims for removal costs and damages must be presented first to the
responsible party (i.e., BP).66 If the party to whom the claim is presented denies all liability, or if
the claim is not settled by payment within 90 days after the claim was presented, the claimant
may elect either to initiate an action in court against the responsible party or to present the claim
directly to the OSLTF.67
The OSLTF managers are limited in the amount of payments that may be awarded for each
incident.68 Under current law, the per-incident cap is $1 billion. Some are now arguing that
58 National Pollution Funds Center, FOSC Funding Information for Oil Spills and Hazardous Materials Releases, April
2003, p. 4.
59 Cynthia Wilkinson et al., “Slick Work: An Analysis of the Oil Pollution Act of 1990,” Journal of Energy, Natural
Resources, and Environmental Law, 12 (1992), p. 188.
60 U.S. Congress, House Committee on Merchant Marine and Fisheries, report accompanying H.R. 1465, Oil Pollution
Prevention, Removal, Liability, and Compensation Act of 1989, H.Rept. 101-242, Part 2, 101st Cong., 1st sess., p. 35.
61 Omnibus Budget Reconciliation Act of 1986 (P.L. 99-509).
62 33 U.S.C. § 2712. The standards and procedural requirements for claims filed against the fund are set forth in the
USCG’s OPA regulations. See 33 C.F.R. §§ 136.1 through 136.241.
63 26 U.S.C. §§ 4611(a)(1) and (2). The Oil Spill Liability Trust Fund is also financed by a per-barrel tax on domestic
crude oil “used in or exported from the United States.” 26 U.S.C. § 4611(b)(1)(A).
64 Prepared by Jonathan L. Ramseur, Specialist in Environmental Policy.
65 OPA Section 1013 (33 U.S.C. 2713). Implementing regulations are found in 33 CFR Part 136.
66 33 U.S.C. § 2713(a). Under OPA, the term “claim” means “a request, made in writing for a sum certain, for
compensation for damages or removal costs resulting from an [oil spill] incident.” 33 U.S.C. § 2701(3).
67 33 U.S.C. § 2713(c). Claims for removal costs must be presented within six years after the date of completion of all
removal activities related to the oil spill incident. 33 U.S.C. § 2712(h)(1).
68 “Incident” means any occurrence or series of occurrences having the same origin, involving one or more vessels,
(continued...)
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increasing the per-incident cap would reduce the risk that parties (private citizens and
governments) would not be fully compensated for losses associated with an oil spill. Statements
from OPA’s legislative history suggest that drafters intended the fund to cover “catastrophic
spills.”69 However, $1 billion today does not have the same value as it did in 1990, when OPA
was enacted. Although OPA requires the President to issue regulations to adjust liability limits at
least every three years,70 an analogous provision for the per-incident cap does not exist. As a point
of reference, if the $1 billion figure had been adjusted for inflation, it would be approximately
$1.6 billion in today’s dollars.
On June 16, 2010, the President announced that BP had agreed to set aside $20 billion to pay
economic damage claims to people and businesses that have been affected by the oil spill. The
claims will be processed by an independent claims facility administered by Kenneth Feinberg. An
accompanying factsheet stated that the facility will develop and publish standards for claims.71 As
of the date of this report, these standards are not yet available. It is uncertain whether these
standards will mirror OPA’s liability framework or to what degree they may differ. Further, it is
uncertain how the independent claims facility will interact with the existing claims process or if
the facility is simply a means by which BP is complying with the process.72
Although the $20 billion fund established by BP may render the per-incident cap a moot issue for
the 2010 Gulf spill, a subsequent catastrophic spill could threaten the current per-incident cap
threshold. As a reference point, the 1989 Exxon Valdez spill tallied approximately $2 billion in
cleanup costs and $1 billion in natural resource damages in 1990 dollars. These combined figures
equate to approximately $5 billion in today’s dollars and would not include the wider array of
claims for which responsible parties are now liable.
Federal Regulatory Framework73
Regulations to implement federal statutes are promulgated by numerous federal authorities and
vastly outnumber federal statutes. The bases for relevant federal regulation in this instance are,
among other statutes, OCSLA74 and the OPA.75 The sheer number of regulations from these
statutes and from other federal laws complicates the description of the regulatory framework.
Frequently, case law, international measures, or other legal actions define the regulatory
parameters that apply to the Deepwater Horizon events. The roles of the lead federal regulators,
BOEMRE/MMS and the U.S. Coast Guard, are outlined below.
(...continued)
facilities, or any combination thereof, resulting in the discharge or substantial threat of discharge of oil. 33 U.S.C.
2701(14).
69 U.S. Congress, House Committee on Merchant Marine and Fisheries, report accompanying H.R. 1465, Oil Pollution
Prevention, Removal, Liability, and Compensation Act of 1989, H.Rept. 101-242, part 2, 101st Cong., 1st sess., p. 36.
70 33 U.S.C. § 2704(d)(4).
71 See http://www.whitehouse.gov/the-press-office/fact-sheet-claims-and-escrow.
72 See http://www.bp.com/sectiongenericarticle.do?categoryId=9033791&contentId=7062345.
73 Prepared by Curry L. Hagerty, Specialist in Energy and Natural Resources Policy.
74 43 U.S.C. § 1331 et seq.
75 33 U.S.C § 2701.
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Bureau of Ocean Energy Management, Regulation, and
Enforcement (BOEMRE, Formerly MMS)
BOEMRE/MMS is the agency within the Department of the Interior with lead regulatory
authority for offshore oil and gas leasing. Regulatory authority in the OCS encompasses resource
assessment and development, operational safety, and environmental considerations.
BOEMRE/MMS regulations generally require that a company with leasing obligations
demonstrate that proposed oil and gas activity conforms to federal laws and regulations, is safe,
prevents waste, does not unreasonably interfere with other uses of the OCS, and does not cause
impermissible harm or damage to the human, marine, or coastal environments.
Three types of regulatory authority govern OCS lease obligations: prescriptive requirements
generally codified in the Code of Federal Regulations, performance-based goals, and consensus-
based technical standards. BOEMRE/MMS regulations cover a wide range of equipment,
procedures, and certifications. BOEMRE/MMS lease stipulations and regulations refer to maps,
communications, and contingencies such as hurricanes and other emergencies. Many of the rules
governing OCS exploration, development, and production are published in the Code of Federal
Regulations.76 The major statutes that govern the leasing process are discussed in the “OCS
Leasing” section.
Once the agency has issued a lease for oil and gas exploration and development rights, a lessee or
operator may submit an application to explore for oil and gas resources. Approval of the
exploration plan by the BOEMRE/MMS regional office is a prerequisite for drilling. After the
exploration phase, if the lessee decides to further develop the area governed by the lease, the
lessee must submit another application, typically a Development and Production Plan or a
Development Operations Coordination Document, for review and approval by BOEMRE/MMS.
In water depths greater than 400 meters (1312 ft.), a lessee would also submit a Deepwater
Operations Plan and a Conservation Information Document. If a lessee seeks to use non-
conventional production or completion technology such as floating or subsea production systems,
BOEMRE/MMS may provide a different approval process. The agency is responsible for
approving applications for a permit to drill (APDs) and subsequent BOEMRE/MMS approvals
are typically required for further drilling actions to sidetrack, bypass, or deepen a well.
It is difficult to determine at what stage in the BOEMRE/MMS approval process applicants
typically address financial assurances, precautionary actions to control development operations,
compliance with design criteria, and compliance with casing and cementing requirements.
Furthermore, it is difficult to determine the agency’s approval process for diverter and blowout
preventer systems in various exploration and development plans. Federal risk assessments are
typically conducted at numerous stages of the exploration and development planning process and
typically depend on risk assessments conducted at a previous stage in the leasing process.
Congress is interested in when risk assessments are conducted, and hearings are underway to
focus on the various stages of the BOEMRE/MMS leasing process. How the agency enforces
regulations and assesses financial penalties for violations, and how it would suspend or shut down
operations under certain conditions, have been raised as concerns since April 20, 2010.
76 See Code of Federal Regulations (30 C.F.R. Chapter 2, Minerals Management Service, Department of the Interior;
40 C.F.R., Protection of the Environment).
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Phases of the OCS leasing process undergo review under the National Environmental Policy Act
(NEPA),77 unless specifically excluded. Generally speaking, NEPA requires an agency to consider
the environmental impacts of its actions and prepare a document describing its analysis.
BOEMRE/MMS prepared four documents describing its environmental analysis related to the BP
lease: an environmental impact statement (EIS) for the five-year plan for all OCS leasing; an EIS
for the combined lease sales in the western and central Gulf of Mexico; an environmental analysis
for Lease Sale 206; and a categorical exclusion for the exploration plan for activity on the
Mississippi Canyon block 252.
A categorical exclusion (CE) may be used under NEPA when an agency has determined that a
type of project does not have significant impacts. A CE can be used unless certain exceptions
exist, typically referred to as extraordinary circumstances, such as the presence of endangered
species or an archeological site. BOEMRE/MMS guidance provides that many exploration plans
in the Gulf can be categorically excluded from further NEPA review. (For a more comprehensive
discussion, see CRS Report R41265, The 2010 Oil Spill: The Minerals Management Service
(MMS) and the National Environmental Policy Act (NEPA), by Kristina Alexander.)
Wells
The operator is required, pursuant to provisions contained in 30 C.F.R. 250, to submit and obtain
approval for an APD. BOEMRE/MMS reviews applications for drilling wells before granting
approval for drilling operations. The lessee is required to take precautions to keep all exploratory
well drilling under control at all times. There is increased interest in what constitutes compliance
with “best available and safest technology” (BAST) to address pressure conditions during drilling
operations, and in the potential for uncontrolled well flow.78 According to OCS regulations,
operators in the Gulf must use BAST whenever practical on all exploration, development, and
production operations.79 However, the regulations also state that, “[i]n general, we consider your
compliance with [BOEMRE/MMS] regulations to be the use of BAST.” The language of the
regulation in effect defines BAST as whatever complies with the agency’s regulation. Some
observers question whether the regulations preclude a more effective approach to BAST.
Platforms
The lessee typically designs, fabricates, installs, uses, inspects, and maintains platforms and
structures on the OCS to assure their structural integrity for the conduct of operations at specific
locations.80 BOEMRE/MMS program personnel typically use certified verification agents to
provide third-party expertise and technical input in the verification process. After installation,
platforms are required to be inspected.81
77 42 U.S.C. § 4321 et seq.
78 Specific requirements for sundry notices for well workovers, completions, and abandonments are detailed in
Subparts D-G of 30 C.F.R. Chapter II.
79 30 C.F.R. 250.107.
80 30 C.F.R. 250.901-904.
81 30 C.F.R. 250.912.
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Equipment and Facilities
Equipment used on the OCS is regulated to assure the safety and protection of the human, marine,
and coastal environments. Surface- and subsurface-controlled safety valves and locks must
conform to federal requirements.82 Facilities also have requirements concerning electrical
systems, flow lines, engines, and firefighting systems.83
Role of U.S. Coast Guard84
The Coast Guard regulates certain activities at mobile offshore drilling units (MODUs) such as
the Deepwater Horizon. The Coast Guard generally overseas the safety of systems at the platform
level of a MODU, as opposed to the sub-platform drilling systems overseen by BOEMRE/MMS.
The areas of Coast Guard oversight include a MODU’s hull structure, navigation equipment,
lifesaving equipment, fire protection equipment and structures, the safety of the electrical system,
and the safety and health of workers as they perform their routine tasks. The Coast Guard
conducts an initial review of a unit before it is allowed to operate. Once a MODU is operating,
the Coast Guard conducts a full survey of the rig every two years and an interim inspection
annually.
The Coast Guard’s regulatory framework for MODUs resembles that for ships calling at U.S.
ports. The “checklist” the Coast Guard uses when inspecting a MODU depends on its “flag” or
country of registration. Like ships engaged in international trade, MODUs on the OCS can be
registered in foreign countries. The Deepwater Horizon was registered in the Marshall Islands.85
Registering a rig or ship in the Marshall Islands or another “flag of convenience” (FOC) country
(Panama, Liberia, and the Bahamas are other common ones) provides tax and other economic
advantages. FOCs are also referred to as “open registries” or “international registries” because
they do not require that a vessel be owned or crewed by citizens of the flag state.86 For these
reasons, the world shipping fleet is predominantly flagged in these countries. According to the
regulatory compliance manager of the Deepwater Horizon, since MODUs can potentially be
moved around the world, international registries provide more flexibility as to where repairs can
be performed, the citizenship of the crew, and the timing of inspections.87 Foreign-flagged rigs
either must meet the design, equipment, and operating standards of the flag state, provided the
Coast Guard determines they are equivalent to or more stringent than U.S. standards
(promulgated at 46 C.F.R. parts 108 and 109), or they must meet the design and equipment
standards contained in the International Maritime Organization (IMO) Code for the Construction
82 30 C.F.R. 250.801.
83 The safety-system devices are tested by the lessee at specified intervals and must be in accordance with numerous
certifications including API RP 14 C, Appendix D, and other measures.
84 Prepared by John Frittelli, Specialist in Transportation Policy.
85 This ship registry began in 1988 partly as a result of political instability in Panama and Liberia at the time. American
interests were instrumental in its creation, as is the case with the Panamanian, Liberian, and other ship registries. The
corporate headquarters of the Marshall Islands registry is located in Reston, VA, and the corporate headquarters of the
Liberian registry is located in Vienna, VA.
86 Elizabeth R. DeSombre, Flagging Standards: Globalization and Environmental, Safety, and Labor Regulations at
Sea (Cambridge, MA: MIT Press, 2006).
87 Oral and written testimony of Warren Weaver, Manager of Regulatory Compliance, Transocean, Ltd. before the
House Committee on Transportation and Infrastructure, Subcommittee on the Coast Guard and Maritime
Transportation, hearing on Foreign Vessel Operations in the U.S. Exclusive Economic Zones, June 17, 2010.
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and Equipment of MODUs (2009 MODU Code, adopted by Resolution A.1023(26)).88 The
Deepwater Horizon was inspected and found to be in compliance with the MODU code.89
The International Maritime Organization (IMO)
The IMO is a U.N. body that has established international standards for the safety, security, and
prevention of pollution from ships. Its first convention, the International Convention for the
Safety of Life at Sea (SOLAS), was adopted in response to the Titanic disaster.90 The MODU
code was developed, beginning in the 1970s, to provide for an equivalent level of safety on
MODUs, as SOLAS does for ships. Countries must ratify IMO conventions and enforce their
requirements. The United States is a signatory to most IMO conventions, including the MODU
IMO convention.91 Like the Coast Guard’s regulatory oversight, the IMO MODU code does not
address the drilling-related equipment of an oil rig.
Classification Societies
The offshore oil industry has also adopted classification societies as an institution of shipping
oversight. Classification societies are independent organizations that inspect a ship or oil rig and
certify that it meets the construction requirements and standards for its intended purpose. They
only inspect the physical elements of a rig, not the qualifications of the crew or how it is operated.
Inspections are performed during the construction phase as well as throughout the operating life
of a unit and become more thorough as the unit ages. Ship and oil rig owners pursue certification
from these societies for mortgage, insurance, and marketing reasons. Deepwater Horizon was
certified mostly by the American Bureau of Shipping (ABS), but also by Det Norske Veritas
(DNV).92 The Coast Guard checks for certification from approved classification societies when
inspecting both foreign and U.S.-flagged vessels or rigs.
Some have questioned the credibility of classification societies, because the societies are paid by
vessel owners. Classification societies typically have a for-profit side of their business, selling
technical expertise to vessel owners, and they compete with each other.93 They date back to the
mid-18th century, when insurers would hire ex-sea captains to survey ships.94 Their pragmatic
knowledge of ships was useful for insurers assessing risk. Eventually, ex-captains were replaced
by naval engineers and technicians and standards were formalized in writing. For marketing
reasons, shipbuilders found it advantageous to build their ships to these standards and therefore
sought and paid for classification. Thus, from an insurer’s or banker’s perspective, a classification
society had a conflict of interest if it was being paid by a ship’s owner. In response, insurers and
banks began creating a separate method of inspection as their confidence in classification
societies eroded. Some of the classification societies established a trade association in 1969 to set
88 See http://www.imo.org/; and search under “MODU” for a brief description.
89 The Deepwater Horizon was built in 2001 and thus the 1989 version of the MODU code was applicable.
90 This convention has been updated since then.
91 See http://www.imo.org/; and select “status of conventions by country.”
92 The Deepwater Horizon’s record of certification and inspection can be viewed at http://cgmix.uscg.mil/PSIX/
PSIXSearch.aspx; searching under the vessel name or its number: 8764597.
93 “Quality Stem to Stern: The Changing Role of Classification Societies,” Marine Technology and SNAME News, vol.
34, no. 3 (July 1997).
94 Philippe Boisson, “Classification Societies and Safety at Sea: Back to Basics to Prepare for the Future,” Marine
Policy, vol. 18, no. 5 (1994), pp. 363-377.
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industry practices to address these concerns.95 In 2004, Congress required that the Coast Guard
not accept certifications by classification societies that are not a member of this trade association
or that have not been approved by the Coast Guard under specified criteria.96
Oil Spill Response Issues
Use of Dispersants97
Dispersants are chemical agents that include surfactants, solvents, and other compounds. By
reducing the connection (referred to as an interfacial tension) between oil and water, dispersants
enhance the breakup of an oil slick into small oil droplets that mix with the water column. Oil
spill dispersants do not reduce the amount of oil entering the environment; instead, dispersants
alter the physical properties of oil, changing its transport, fate, and potential effects.98
In general, the decision to use dispersants poses trade-offs for oil spill responders. The objective
of dispersant use is to minimize the amount of surface oil that reaches shoreline habitats, where it
threatens a wide range of wildlife and organisms. The downside is that dispersants increase the
exposure to oil of organisms living in the water column. As stated in a 2005 National Research
Council study, “[d]ispersant application thus represents a conscious decision to increase the
hydrocarbon load (resulting from a spill) on one component of the ecosystem (e.g., water column)
while reducing the load on another (e.g., coastal wetland).”99
Section 311(d) of the Clean Water Act (33 U.S.C. 1251 et seq.) requires EPA, in cooperation with
the states, to prepare a schedule of dispersants, other chemicals, and other spill-mitigating devices
and substances. The Product Schedule100 includes dispersants and other chemical or
bioremediation products that may be authorized for use on oil discharges in accordance with the
procedures set forth in the National Contingency Plan (NCP).
EPA may add products to the NCP Product Schedule after companies submit specific data to the
agency. Data requirements include results from effectiveness and toxicity testing. Although EPA
reserves the right to verify testing data (and to require additional information), the regulations do
not establish a toxicity threshold for placement on the schedule. A decision that a product is
eligible for listing on the Product Schedule does not constitute EPA approval of the product.
As part of their oil spill response preparations, Regional Response Teams (RRTs) and Area
Committees address the desirability of using dispersants and other oil control agents in particular
situations. Planners consider the potential sources and types of oil that might be spilled, the
existence and location of environmentally sensitive resources that might be impacted by spilled
95 The International Association of Classification Societies (IACS).
96 The Coast Guard and Maritime Transportation Act of 2004 (P.L. 108-293, § 413). The Coast Guard issued a notice
of proposed rulemaking on April 23, 2010; 75 Fed. Reg. 21212.
97 Prepared by Jonathan L. Ramseur, Specialist in Environmental Policy.
98 For a more comprehensive discussion, see National Research Council, Oil Spill Disperants: Efficacy and Effects,
National Academies Press, 2005.
99 Ibid.
100 EPA, National Contingency Plan Product Schedule, May 2010, http://www.epa.gov/emergencies/docs/oil/ncp/
schedule.pdf.
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oil, available product and storage locations, the availability of equipment and adequately trained
operators, and the available means to monitor product application and effectiveness. Regional
Contingency Plans and Area Contingency Plans may preauthorize dispersants and the specific
contexts in which products should and should not be used, and many regions/areas have done so,
including those in the Gulf.101 Before authorizing dispersant use in an area without a
preauthorization plan, an On-Scene Coordinator must (1) seek and receive “concurrence” with the
RRT representative from EPA and representatives from states with jurisdiction; and (2), when
practicable, consult with trustees from the Departments of Commerce and Interior.
An unprecedented volume of dispersants have been applied to the oil spill in the Gulf. While
dispersants have proven effective in breaking up the oil on the surface, numerous questions
remain regarding the fate of the dispersed oil and the chemical dispersants. Moreover, the
application of undersea dispersants is essentially experimental.102 Many have raised questions
about the toxicity of the dispersant BP has been using in the Gulf. Although it is on the NCP
schedule, other dispersants are listed as both more effective and less toxic.103
On May 20, 2010, EPA and the Coast Guard directed BP to evaluate available, preapproved
dispersants for toxicity and effectiveness.104 On May 22, BP responded by (generally) concluding
that the dispersant being used (COREXIT) continues to be the best option.105 On May 26, 2010,
EPA and the Coast Guard directed BP to “eliminate the surface application of dispersants. In rare
cases when there may have to be an exemption, BP must make a request in writing to the FOSC
[the Coast Guard OSC] … to justify the use of surface application. The FOSC must approve the
request and volume of dispersant prior to initiating surface application” (emphasis added).106
When this directive was made, BP had applied 700,000 gallons of dispersants to the surface
waters. Since the directive, responders have applied an additional (approximately) 300,000
gallons on the surface, at a fairly consistent daily rate (Figure 2). However, data indicate (as of
June 16) that June 6 was the last surface application. For up-to-date information from EPA, see
http://www.epa.gov/bpspill; for more current dispersant application data, see
http://www.deepwaterhorizonresponse.com.
101 See Figure 2-1 in National Research Council, Oil Spill Disperants: Efficacy and Effects, National Academies Press,
2005.
102 Nancy Kinner (co-director of the Coastal Response Research Center), testimony before the House Committee on
Transportation and Infrastructure, May 19, 2010.
103 More information is available at EPA’s website, at http://www.epa.gov/bpspill/dispersants.html.
104 See http://www.epa.gov/bpspill/dispersants/bp-hayward-dhs-epa.pdf.
105 See http://www.epa.gov/bpspill/dispersants/5-21bp-response.pdf.
106 See http://www.epa.gov/bpspill/dispersants/directive-addendum3.pdf.
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Figure 2. Dispersant Application in Gulf Oil Spill
1,200,000
1,000,000
800,000
llons
600,000
a
G
400,000
200,000
0
10
10
10
10
10
10
10
10
10
10
10
10
23/
30/
7/
14/
21/
28/
4/
11/
18/
25/
2/
9/
4/
4/
5/
5/
5/
5/
6/
6/
6/
6/
7/
7/
Surface Application
Subsurface Application
Source: Prepared by CRS with data from daily “Current Operations” updates, available at
http://www.deepwaterhorizonresponse.com.
Notes: Data for some days were not available. In these instances, the volume for the previous day was used.
Louisiana Protective Berm Project107
On May 11, 2010, the U.S. Army Corps of Engineers (Corps) received a request from the state of
Louisiana’s Coastal Restoration and Protection Authority (LCRPA) for an emergency permit to
construct a project of approximately 86 miles of sand berms in order to protect Louisiana’s barrier
islands and coastal wetlands from damage by the Deepwater Horizon oil spill.108 Supporters of
the plan to construct the protective berms (including federal agencies and nongovernmental
entities) argue that the project is a promising means to mitigate the effects of the oil spill in
Louisiana. They note that the urgent situation associated with the oil spill requires that the project
move forward with maximum speed and regulatory flexibility. These observers contend that,
combined with other natural barriers in the Gulf, strategically placed berms of relatively small
size and minimal cost will protect large areas of coastline and wetland habitat from oil pollution.
Some have expressed doubts regarding the barrier project. Specifically, agency and
nongovernmental stakeholders have questioned the feasibility and effectiveness of the barriers.109
Further, some scientists—including those from the National Oceanic and Atmospheric
107 Prepared by Charles V. Stern, Analyst in Natural Resources Policy.
108 Under 33 C.F.R. § 325(b), authorization (through a permit) by the Corps of Engineers is required to conduct certain
regulated activities within waters of the United States. This requirement is maintained during emergencies, although the
Corps has modified procedures to expedite permit processing during an emergency under 33 C.F.R. § 235.2(e)(4).
109 One of the main critiques associated with feasibility of the project is timing. By some estimates, even if construction
is initiated immediately, it would not be complete until the end of the calendar year. Additionally, questions have been
raised as to the ability of the berms to withstand tidal fluctuations and storms, including hurricanes.
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Administration (NOAA), the U.S. Geological Survey (USGS), and the Fish and Wildlife Service
(FWS)—have expressed preliminary concerns about the potential of the barriers to disrupt tidal
currents and ocean circulation patterns, and to have other long-term environmental impacts.110
These observers note the unprecedented nature of large-scale berm construction of this type, and
advocate for a significant degree of caution moving forward on this project.
The original request by LCPRA proposed to construct 86 miles of berms standing 6 feet above the
mean high water line in and around areas near Louisiana barrier islands in the Gulf. The plan
called for the berms to be built largely from dredge and fill materials taken from nearby areas
(including some barrier islands), and to leave open certain deepwater channels for tidal influx.
The State of Louisiana estimated the preliminary cost of this plan to be $350 million. After
subsequent discussions between LCPRA and the Corps, the state submitted a new permit request
that revised the location from which certain borrowed materials would be taken, as well as the
coverage areas of the berms themselves. The revised request was submitted on May 14, 2010, and
circulated by the Corps for interagency comment on May 17, 2010.111 This revised version of the
plan requested 128 miles of barriers over 19 separate areas (also known as reaches). Construction
of the revised plan was estimated to take six to nine months, and no cost estimate was provided
for this version of the plan.
Following interagency coordination and submission of comments, the Corps partially approved
the LCPRA request on May 27, 2010. The Corps permit noted that approval of the project did not
eliminate the need for a number of other associated requirements, including an FWS Special Use
Permit, a Louisiana Coastal Use Permit, and approval from BOEMRE/MMS to dredge certain
offshore borrow sites.
The Corps approved six reaches (four reaches to the west of the Mississippi River Delta, and two
reaches to the east) of the revised request by the state.112 The final Corps environmental analysis
noted that the state’s proposal was not selected in its entirety because of its potential to increase
tidal circulation and reduce pathways for the oil to be flushed back out to sea.113 Additionally, the
Corps highlighted concerns with the longevity of the structures and the timing of construction.
The Corps concluded that the selected six reaches would offer the greatest immediate benefits
without adverse environmental impact. The Corps noted that subsequent construction decisions
may be based on monitoring of the initial structures.
Responsibility for financing and construction of the approved reaches of berm is an ongoing
concern. In early June, National Incident Commander Thad Allen announced that the federal
government would direct BP to pay for all six reaches approved by the Corps.114 BP announced
support for this decision and estimated the cost for construction of the approved plan to be $360
110 Concerns with the barriers are noted in the final permitting documents at http://155.76.147.200/news/
Emergency%20Permit%20Documents%20Compressed%20FINAL.pdf. Additionally, Admiral Allen noted the initial
concerns of Dr. Jane Lubchenco, NOAA Administrator, with the barriers at a press conference on June 2, 2010. See
http://www.deepwaterhorizonresponse.com/go/doc/2931/581707/.
111 The request was revised in part because the original proposal for a coastal restoration project did not qualify under
Corps emergency authorization procedures.
112 The original request included 19 reaches of berm (15 reaches to the west of the Mississippi River Delta and four
reaches to the east).
113 See environmental analysis by the Corps at http://155.76.147.200/news/
Emergency%20Permit%20Documents%20Compressed%20FINAL.pdf, pp 88-89.
114 See http://www.deepwaterhorizonresponse.com/go/doc/2931/585863/. Accessed June 3, 2010.
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million.115 Notably, while BP has agreed to make payments based on project milestones, it has
also stated that it will not manage project construction or assume any liability associated with the
project.116
Congress may consider what role, if any, the federal government should play in construction,
upkeep, and monitoring of the Barrier Island Project. Responsibility for management of the
barriers’ construction has not been formalized, although National Incident Commander Thad
Allen has previously asserted that the state will have primary responsibility.117 Additionally, it is
unclear who will assume ownership and liability of the barriers after they are constructed, and
over what period of time the barriers will be maintained. Maintenance and monitoring
requirements could result in additional costs beyond the original construction estimates, and BP
has not indicated whether it will accept any additional responsibility for these elements. Finally, it
is unclear whether other states in the Gulf region intend to pursue similar barrier strategies in
response to the oil spill, and whether federal decisions on the Louisiana project would apply to
these and other future efforts.
Relief Wells118
On May 2, 2010, 12 days after the Deepwater Horizon drill rig exploded and caught fire, BP
began drilling the first of two relief wells, with the goal of intersecting the Deepwater Horizon
well near the bottom and plugging it with heavy mud and cement. At the request of the Obama
Administration, BP began drilling a second relief well on May 16 to provide a second chance at
plugging the well if the first relief well failed. Both wells are being drilled vertically and then
turned at an angle to intercept the Deepwater Horizon well just above the oil- and gas-producing
reservoir at about 18,000 below sea level. (See Figure 3.) As of June 13, 2010, the first relief well
had reached 13,973 feet and had begun to drill at an angle of 35 degrees; the second relief well
had reached 9,022 feet and was still drilling vertically. BP and the Administration estimate that it
will take several months, possibly until August, for the first relief well to reach the target area.119
What Are Relief Wells?
A relief well is drilled and constructed similarly to an exploration well but for a different purpose.
Instead of drilling to intersect a petroleum-bearing horizon and to produce oil and gas, a relief
well is drilled to intersect an out-of-control well that suffered a blowout. The relief well is guided
to the blown-out well and drilled into the existing well casing, and then heavy drilling mud and
cement are injected into the well to form a permanent plug. The plug is intended to prevent oil
115 In light of questions raised about the original cost estimate by the state of Louisiana for the larger project during the
interagency comment period, BP appears to have used a more conservative estimate for the six reaches approved by the
Corps.
116 See http://www.bp.com/genericarticle.do?categoryId=2012968&contentId=7062613.
117 See, for example, June 2 press briefing by Admiral Thad Allen, at http://www.deepwaterhorizonresponse.com/go/
doc/2931/581707/.
118 Prepared by Peter Folger, Specialist in Energy and Natural Resources.
119 Deepwater Horizon Response site, Ongoing Response Timeline, at http://www.deepwaterhorizonresponse.com/
posted/2931/updated_timeline_June_10.594723.pdf. Greg Bluestein and Jason Dearen, “Spill Relief Well Draws
Scrutiny,” Associated Press, June 13, 2010., at http://news.yahoo.com/s/ap/20100613/ap_on_bi_ge/
us_gulf_oil_spill_relief_wells.
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and gas from flowing from the petroleum-bearing reservoir into the wellbore of the blown-out
well and up to the surface.
Figure 3. Image of Two Relief Wells Being Drilled by BP to Plug the Deepwater
Horizon Well
Source: BP, modified by CRS.
Notes: Relief wel 1 had reached a depth of 13,973 feet below sea level and relief wel 2 had reached 9,022 feet
as of June 13, 2010. Numbers listed next to the trace of the relief wel locations indicate the diameter of casing
at that point (e.g., CSG-36 indicates 36-inch diameter casing).
Examples of Relief Wells Being Used to Stop Blowouts
On June 3, 1979, more than 30 years prior to the Deepwater Horizon disaster, the Ixtoc I
exploration well blew out in the Bay of Campeche, Mexico, resulting in a rig fire and subsequent
sinking of the rig into 167 feet of water in the southern Gulf of Mexico. According to NOAA, the
blowout resulted in the release of 10,000 to 30,000 barrels of oil per day until the leak was
stopped on March 23, 1980, 290 days later.120 According to reports, two relief wells were drilled
to intersect the well near the petroleum-bearing reservoir after other attempts to cap the well on
120 National Oceanic and Atmospheric Administration, National Ocean Service, Office of Response and Restoration,
Incident News, at http://www.incidentnews.gov/incident/6250.
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the seafloor failed. Relief well Ixtoc 1A was spudded121 in the middle of June and relief well Ixtoc
1B was spudded in the middle of July.122 Ixtoc 1A reached the petroleum-bearing reservoir in the
second week of February, approximately eight months after relief well drilling began. Mud
pumped through the relief wells finally stopped the uncontrolled leak in Ixtoc 1 five weeks
later.123
On August 21, 2009, a drill rig operating in the Montara oil field about 140 miles northwest of the
northern Australian coastline suffered a blowout and uncontrolled release of oil on the seafloor in
water approximately 240 feet deep. It is still unclear how much oil was leaking per day, although
the rig operator initially estimated that about 400 barrels per day were being released into the
ocean. Other reports indicate that as many as 2,000 barrels per day were leaking.124 A relief well
was drilled to intersect the original well near the petroleum-bearing reservoir approximately
13,000 feet below the ocean bottom. After multiple attempts, mud injected into the leaking well
finally stopped the leak on November 3, about 10 weeks after the initial blowout.125 A
commission appointed by the Australian Minister for Resources and Energy is investigating the
blowout, and is expected to release a report sometime in June 2010.126
Relief Well Policies
Relief wells are mentioned in several places in federal regulations that govern offshore oil and
gas development for the U.S. OCS, which includes the U.S. Gulf of Mexico.127 Under 30 C.F.R.
§ 250.213, an exploration plan (EP) approved by BOEMRE/MMS for oil and gas operations in
the OCS must show that a company has or will have the financial capability to drill a relief well
or conduct other emergency well control operations. The EP must also indicate the availability of
a rig to drill a relief well, and an estimate of the time it would take to drill a relief well. Under 30
C.F.R. § 250.243, a company’s development and production plan, or development operations
coordination documents, must also contain the same information: financial capability, rig
availability, and estimated time to drill a relief well. The current regulations do not indicate that a
drill rig must be on-site and ready to drill a relief well if a blowout occurs.
An exhaustive review of regulations governing relief wells in other countries is beyond the scope
of this report. However, news reports have frequently cited Canadian policies regarding relief
wells.128 An issue for Canada that is not pertinent to the Gulf of Mexico is offshore drilling in
regions where sea ice covers the ocean surface during the colder months, and the possible need to
drill a relief well during the months when the sea is ice-free (a so-called “same-season” relief
well). For example, if an offshore well suffers a blowout and uncontrolled leak at the end of the
drilling season, a relief well drilled to curtail the blowout may not have sufficient time to reach
121 To “spud” a well means to start drilling into the sediments and rock.
122 Arne Jernelöv and Olof Lindén, “Ixtoc I: A Case Study of the World’s Largest Oil Spill,” Ambio, vol. 10, no. 6
(1981).
123 Ibid.
124 Keith Bradsher, “Relief Well Was Used to Halt Australian Spill,” New York Times, May 2, 2010.
125 Ibid.
126 See http://www.montarainquiry.gov.au/index.html for more information on the Montara oil spill.
127 See 30 C.F.R. § 250 for the regulations covering oil and gas operations in the OCS.
128 See, for example, Greg Bluestein and Jason Dearen, “Spill Relief Well Draws Scrutiny,” Associated Press, June 13,
2010; and Peter Overby, “BP Sought to Ease Canada’s Policy on Relief Wells,” NPR, June 3, 2010, at
http://www.npr.org/templates/story/story.php?storyId=127381814.
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the well and inject mud and cement before the winter ice forms and causes drilling operations to
cease. The “same-season” relief well issue is of concern to offshore drilling in the Beaufort Sea
(which also borders parts of Alaska), but may not necessarily be an issue for offshore drilling off
the coasts of Newfoundland, Labrador, or Nova Scotia.
According to the Canadian National Energy Board, which governs offshore drilling in the
Beaufort Sea, the regulations require project-specific contingency plans that must include all
measures to respond to an emergency situation with an offshore well.129 The Beaufort Sea
regulations contain a definition for relief well (“a well drilled to assist in controlling a blow-out in
an existing well”), but do not contain language specifically requiring a relief well as part of the
contingency plan.130 Offshore drilling in Canada is also governed regionally by joint federal-
provincial accord agreements, and regulated under the Canada-Newfoundland and Labrador
Offshore Petroleum Board and the Canada-Nova Scotia Offshore Petroleum Board.131 In a letter
to the editor of the Ottawa Citizen, the chairs of the Canada-Newfoundland and Labrador
Offshore Petroleum Board, the Canada-Nova Scotia Offshore Petroleum Board, and the National
Energy Board wrote:
The new drilling and production regulations state that companies are required to provide
contingency plans describing how they plan to mitigate the effects of any reasonably foreseeable
event that might compromise safety or environmental protection, which absolutely would include
mitigating the effects of a blowout. Relief wells are a proven method of regaining well control
and none of the regulatory boards would authorize companies to conduct any drilling or
production activities if the contingency plans did not adequately address the drilling of a relief
well.132
In response to some statements that relief well regulations have been relaxed under the current
Canadian government, Christian Paradis, Minister of Natural Resources for Canada, wrote:
Drilling program guidelines pertaining to relief wells have remained the same since 1990. These
guidelines specifically address the issue of relief wells, and explicitly state that “operators are
expected to identify an alternate drilling installation for relief well purposes and provide a
description of its operating capability, its location, contractual commitments, and state of
readiness.” The adequacy of these arrangements constitutes a crucial aspect of the board’s
decision of whether or not to issue an authorization to drill in the first place. 133
Issues for Further Consideration
Establishing a new policy for relief wells has captured the interest of the Administration and
Congress. In response to a question about requiring oil companies to drill relief wells
simultaneously to the production of oil, Coast Guard Admiral Thad Allen stated that it would be a
129 E-mail from Sarah Kiley, Communications Officer, National Energy Board (Canada), June 11, 2010.
130 Under the Canada Oil and Gas Drilling and Production Regulations, Part 2—Management System, Application for
Authorization and Well Approvals, Application for Authorization, the application for authorization “shall be
accompanied by … contingency plans, including emergency response procedures, to mitigate the effects of any
reasonably foreseeable event that might compromise safety or environmental protection.” See http://laws.justice.gc.ca/
PDF/Regulation/S/SOR-2009-315.pdf.
131 E-mail from Sarah Kiley, Communications Officer, National Energy Board (Canada), June 11, 2010.
132 Max Ruelokke, Diana Dalton, and Gaétan Carron, “Address Relief Wells,” Ottawa Citizen, June 11, 2010.
133 Christian Paradis, “Drilling Guidelines on Relief Wells the Same,” Ottawa Citizen, June 14, 2010.
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legitimate point to be raised and put in front of the national commission on the BP oil spill
established by President Obama.134 On June 15, 2010, Senator Lautenberg introduced S. 3492, the
Emergency Relief Well Act, that would require the concurrent drilling of at least one relief well
whenever a new exploratory or development well is drilled. A requirement to drill a relief well
concurrently with a new exploratory or development well would raise a number of safety and
economic issues for offshore drilling.
A rationale for drilling a relief well concurrently with drilling and exploration or development
well would be to shorten the time, possibly by months for deep wells, between a blowout and
when a leak is plugged. For example, the two relief wells now being drilled to intercept the
Deepwater Horizon well are expected to take several months to reach the target zone. Plugging a
well in days or weeks instead of months could prevent large quantities of oil and gas from leaking
from a blown-out well that otherwise would leak over the time it takes to drill a relief well. The
actual drilling and completion of a relief well, however, would likely require the same or even
greater attention to safety so as not to experience a similar blowout while drilling into the same
geological formation. Thus drilling a relief well is not a risk-free proposal, and a possibility
would still exist for anomalous gas “kicks”135 in the well and for a blowout if the gas kicks are not
prevented or controlled.
Drilling a relief well with the same equipment needed for an exploration and development well,
such as semi-submersible drilling platforms, marine risers, casing, cement, and blowout
preventers, would likely mean that the cost to drill an exploration or development well would rise
significantly compared to current practices. Whether costs would double—twice the wells
required compared to current practices—is unclear, and might depend on whether a
simultaneously drilled relief well could ultimately also be used for exploration, development, or
production in the same oil and gas field.
For deepwater and ultra-deepwater drilling requiring semisubmersible rigs or drill ships capable
of drilling 4,000 feet or more below the seabed, the average daily rate for the drill rigs exceeds
$400,000 per day.136 The time to drill and complete a well depends on water depth and how deep
the petroleum-bearing reservoir lies beneath the seabed. Deeper water and deeper reservoirs
require more time to drill. For example, BP began drilling the Deepwater Horizon well in 5,000
feet of water on October 21, 2009. BP halted operations on November 28 because of damage to
the rig caused by Hurricane Ida, resumed drilling on February 3, 2010, and was nearing
completion of the well at a depth of 18,000 below sea level on April 20 when the blowout and fire
occurred. Total time drilling until the disaster was approximately 114 days. Assuming drill rig
costs of $400,000 per day, the Deepwater Horizon well rig costs were approximately $45 million
when the April 20 accident occurred. Presumably, costs to drill a concurrent relief well would be
approximately the same. Currently there are 31 drill rigs operating in 5,000 feet or deeper waters
in the U.S. Gulf of Mexico.137
134 White House Press Briefing by Press Secretary Robert Gibbs and National Incident Commander Admiral Thad
Allen, June 7, 2010, at http://www.whitehouse.gov/the-press-office/press-briefing-press-secretary-robert-gibbs-and-
national-incident-commander-admiral.
135 A “kick” is the flow of reservoir fluids into the wellbore during drilling operations.
136 Rigzone, Offshore Rig Day Rates, at http://www.rigzone.com/data/dayrates/.
137 As reported by Rigzone, Offshore Rig Search, at http://www.rigzone.com/data/advanced_search.asp, as of June 17,
2010.
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An option to have a drill rig “standing by” but not actually drilling a relief well unless the
exploration or development well experienced a blowout might be less costly than drilling two
concurrent wells. If a blowout occurred, then the relief well would be positioned to begin drilling
immediately. During the Deepwater Horizon incident, 12 days elapsed before the first relief well
was spudded. Nevertheless, the Deepwater Horizon relief wells will take months to drill, so
whether the time saved—and quantity of oil leaked—would be worth the expense of keeping a
drilling operation on “stand-by” is another challenging policy issue.
Response Vessels and the Jones Act138
A law commonly known as the Jones Act requires that cargo transported between any two U.S.
points be transported by a U.S.-built, -owned, and -documented vessel (requiring a U.S. crew).139
This law applies to oil spill response vessels, such as skimmers, operating within 3 miles of the
U.S. coastline. The law does not apply to response vessels outside the 3-mile limit, and as of June
15, 2010, 15 foreign-flagged vessels were engaged in oil spill cleanup activities.140 Within the
3-mile limit, foreign oil spill response vessels can be used if there is an inadequate supply of U.S.
oil spill response vessels and the foreign country has a reciprocal agreement with the United
States.141 The U.S. Maritime Administration is responsible for checking on the availability of U.S.
vessels if a waiver is requested and in one instance with regard to the current spill found that U.S.
vessels were available to perform the task.142 Some contend that the Jones Act is hindering
cleanup efforts by delaying or preventing foreign offers of assistance, while others contend that
many U.S. oil spill response vessels are sitting idle. The National Incident Command Center has
stated that no offers of foreign assistance have been declined because of the Jones Act.143
Dredging must also be performed by U.S. vessels, and thus this requirement would be applicable
to the Louisiana Protective Berm Project.144 For vessels not considered to be oil spill response
vessels, a Jones Act waiver could be obtained pursuant to 46 U.S.C. § 501, which also requires a
determination that not enough U.S. vessels are available.
Investigations and Commissions145
Several investigations and commissions have been initiated to look into various issues
surrounding the Deepwater Horizon incident. For the most part, these examinations are still in
their early stages.
138 Prepared by John Frittelli, Specialist in Transportation Policy.
139 46 U.S.C. § 55102.
140 Coast Guard press release dated June 15, 2010, at http://www.deepwaterhorizonresponse.com/go/doc/2931/660195.
141 46 U.S.C. § 55113.
142 Written testimony of David T. Matsuda, Acting Maritime Administrator, before the Subcommittee on the Coast
Guard and Maritime Transportation, House Committee on Transportation and Infrastructure, hearing on Foreign Vessel
Operations in the U.S. Exclusive Economic Zones, June 17, 2010.
143 National Incident Command, “Jones Act Fact Sheet,” June 18, 2010, at http://www.deepwaterhorizonresponse.com/
posted/2931/MARAD_revised_Jones_Act_Fact_Sheet.670991.pdf.
144 46 U.S.C. §§ 55109, 55110.
145 Prepared by Jonathan L. Ramseur, Specialist in Environmental Policy.
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• The President directed the Secretary of the Interior to provide a study of current
safety measures for OCS activities. Made available on May 27, 2010,146 the
study—Increased Safety Measures for Energy Development on the Outer
Continental Shelf—was the first of several formal investigatory measures related
to the Deepwater Horizon accident and oil spill.
• The Secretaries from the Departments of the Interior and Homeland Security
directed the Coast Guard and BOEMRE/MMS to conduct a joint investigation.
The objective of the investigation is to develop conclusions and
recommendations as they relate to the Deepwater Horizon explosion and loss of
life on April 20, 2010.147
• President Obama established the Bipartisan National Commission on the BP
Deepwater Horizon Oil Spill and Offshore Drilling. The commission is tasked
with providing recommendations on how to prevent—and mitigate the impact
of—any future spills that result from offshore drilling. The commission’s first
meeting was on July 12.
Many companies (including BP), trade groups, and industry standards organizations are
conducting internal reviews. The focus of private-sector investigations tends to include testing the
use of blowout preventers and other procedures, as well as testing other safety, communications,
and operational procedures.
Environmental and Economic Impacts
Oil spills can cause significant harm to living organisms that inhabit ocean and coastal areas and
may result in significant costs to businesses and the public. Coastal areas may be especially
vulnerable because of oil stranding in wetlands and other coastal ecosystems. Oil coating, and
absorption or ingestion of oil, result in direct mortality and sublethal effects that reduce the fitness
of organisms. For example, oil can coat small animals and plants that inhabit shoreline areas and
suffocate them. The uptake of dissolved components of oil may be toxic for fish, shellfish, and
other invertebrates and plankton. Birds and fur-bearing marine mammals are among the most
vulnerable species. When coated by oil, they lose protection and body heat maintained by their
feathers and fur, and they may also ingest oil when preening. Coastal habitats may require years
or decades to recover from lethal levels of oil exposure.
Environmental Impacts148
When natural resources are affected by oil spills, services that benefit the public may be damaged.
Services can be divided into different categories, depending on the nature of the benefits they
provide:149
146 The May 27 study is available at http://www.doi.gov/deepwaterhorizon/loader.cfm?csModule=security/getfile&
PageID=33598.
147 More information is available at http://www.restorethegulf.gov/investigation.shtm.
148 Prepared by Harold F. Upton, Analyst in Natural Resources Policy.
149 Walter Reid et al., Millennium Ecosystem Assessment: Ecosystems and Human Well-being (Washington, DC: Island
Press, 2005).
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• Supporting services—processes that provide the foundation for all ecosystem
services, such as nutrient cycling and primary production.
• Provisioning services—direct material benefits that humans receive from the
products of ecosystems, such as food (fisheries), timber, and genetic resources.
• Regulating services—indirect benefits provided by natural systems, such as
retaining and purifying of water in wetlands or mitigation of natural hazards
(e.g., storms) by coastal marshes and mangrove forests.
• Cultural services—a broad category that includes the general values humans
place on natural areas. Benefits may be gained through direct use, such as
recreational activities (recreational fishing and swimming), or through the value
placed by the public on the continued existence of natural resources, including
aesthetic values, bequest or generational values, and community and spiritual
connections to natural resources.
Natural Resource Damage Assessment and Compensation
OPA addresses natural resource damages and the restoration of resources that are injured and
services that are lost as the result of an oil spill. Designated federal, state, tribal, and sometimes
foreign trust agencies are responsible to act on behalf of the public. OPA directs trustees to
undertake two main actions: (1) return injured natural resources to their baseline condition (the
condition that existed prior to the spill), and (2) recover compensation for interim losses.
Restoration actions focus on returning natural resources to the baseline level with as much
certainty and as quickly as possible. Compensation includes actions to address interim losses of
natural resources and services until resources have recovered. Compensatory actions provide
services of the same type and quality and of comparable value as those lost or injured. Damage
assessment is required to quantify the extent of injuries to natural resources and to determine the
type and amount of restoration and compensatory actions needed. The process of recovery can be
broken down into three main phases:150
• Pre-assessment phase—determines whether natural resource injuries have
occurred or are expected and whether to continue to the next phase.
• Restoration planning phase—evaluates potential injuries to natural resources.
This phase includes an assessment of the nature and extent of natural resource
injuries and development of plans for restoring the resource and compensating
the public for interim losses.
• Restoration phase—the final restoration plan is presented to responsible parties
to implement or fund the plan. This provides the opportunity for settlement of
damages claims without litigation. However, OPA authorizes trustees to bring
civil action for damages.
In addition, natural resource impacts may disrupt business activity, especially sectors that depend
directly (or indirectly) on natural resources and the environment. Direct economic losses may
accrue from the closure of fishing grounds, effects on port operations, or the loss of tourist-related
business. Unlike natural resource damages, which are considered by the appropriate natural
150 Department of Commerce, “Natural Resource Damage Assessments; Final Rule,” 61 Federal Register 441-442,
January 5, 1996.
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resources trustees, costs to businesses are submitted as claims by the third parties that suffer the
loss (as discussed above in “OPA Compensation and Claims Process”).
Environmental Recovery
NOAA regulations state that recovery means the return of injured natural resources and services
to baseline.151 Defining the baseline condition of the ecosystem is often hindered by limited
scientific understanding of physical and biological processes in coastal and marine areas, natural
variability of marine systems, and a paucity of related scientific data. These factors are coupled
with uncertainties about acute and chronic effects of oil on marine organisms. In the face of these
uncertainties, it is likely that many questions related to restoration and compensation will arise,
including basic questions about what constitutes ecosystem recovery and when it has occurred.
Economic Impacts
Natural Resources and Related Economic Activity152
Natural resource-dependent sectors of the Gulf coastal economy that have been affected by the oil
spill include commercial and recreational fisheries and the tourist industry. In 2008, the Gulf
fishing industry landed 1.274 billion pounds of fish and shellfish with a dockside value of $659
million.153 When related processor, wholesale, and retail businesses are included, the Gulf
seafood industry supports over 200,000 jobs with related income impacts of $5.5 billion.154 The
top commercial species in terms of value are shrimp ($367 million), menhaden ($64 million),
oysters ($59 million), and blue crab ($38 million).155 Recreational fisheries also make significant
contributions to the region’s economy. In 2008, recreational anglers took 25.4 million fishing trips
and spent over $12 billion on equipment and trips in the Gulf region.156 Some of the most popular
recreational species include snappers, several types of drum, sheepshead, and Spanish mackerel.
Recreational fisheries support businesses such as charters and bait and tackle shops, and services
such as restaurants and hotels. In 2000, 21.9 million people visited Gulf beaches and accounted
for 177.2 million beach days.157 The tourist industry contributed 620,000 jobs and over $9 billion
in wages to the Gulf region. On the other hand, jobs related to cleanup activities could mitigate
some of the losses in the fishing and tourism industry.
Immediate economic injuries of the oil spill have been incurred by the Gulf of Mexico fishing
industry. As of July 14, 2010, NOAA had closed 83,927 square miles of the Gulf to commercial
and recreational fishing (Figure 4).158 This is approximately 35% of the federally managed waters
151 Ibid. p. 441.
152 Prepared by Harold F. Upton, Analyst in Natural Resources Policy.
153 National Marine Fisheries Service, U.S. Department of Commerce, Fisheries Economics of the United States, Silver
Spring, MD, 2008, http://www.st.nmfs.noaa.gov/st5/publication/econ/2008/FEUS%202008%20ALL.pdf.
154 Ibid.
155 Ibid.
156 Ibid.
157 Brent Ache, David Bylsma, and Kristen Crossett, et al., The Gulf of Mexico at a Glance, National Ocean Service,
NOAA, A Tool for the Gulf of Mexico Alliance and the American Public, Washington, DC, 2008,
http://gulfofmexicoalliance.org/pdfs/gulf_glance_1008.pdf.
158 See http://sero.nmfs.noaa.gov/deepwater_horizon_oil_spill.htm.
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of the Gulf Exclusive Economic Zone.159 Portions of Louisiana, Alabama, Mississippi, and
Florida state waters have also been closed. These areas are some of the richest fishing grounds in
the Gulf for major commercial species such as shrimp, blue crab, and oysters. Fishermen have
filed claims with BP for economic injuries, and claims are being paid out to individuals on a
monthly basis. As the supplies of Gulf oysters, shrimp, and crabs have decreased, prices for these
items have increased. Imports of shrimp are likely to increase to substitute for lost domestic
production.160 The seafood industry is also very concerned with consumers’ perceptions of Gulf
seafood and potential effects on demand for Gulf seafood products. To ensure seafood safety,
NOAA and FDA are monitoring fish caught just outside closed areas and testing them for oil
compounds. Bookings and trips for recreational fishing charters have decreased, especially in
Louisiana, and sportfishing tournaments have been cancelled.
Figure 4. Gulf of Mexico Fishery Closure
(as of July 14, 2010, unchanged from July 12, 2010))
Source: NOAA, http://sero.nmfs.noaa.gov/deepwater_horizon_oil_spill.htm.
Notes: For more recent closing announcements, see NOAA’s website, at http://sero.nmfs.noaa.gov/
deepwater_horizon_oil_spill.htm.
159 The exclusive economic zone includes the area between 3 and 200 nautical miles from shore.
160 The United States imports 90% of the shrimp it consumes.
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Oil has reached many central Gulf of Mexico beaches, and visits to these areas have decreased
significantly. Cancellations have also been reported for areas that are still clear of oil. Tourism
officials are concerned that reporting on the spill has contributed to negative perceptions of the
entire Gulf region. To counter these perceptions, BP has funded tourism promotion programs in
Alabama, Mississippi and Florida. Fishing and tourism have already been harmed by the
Deepwater Horizon spill, but it is likely that the largest impacts have not yet surfaced and may
occur over years.
Impact on Oil and Natural Gas Prices161
The Deepwater Horizon incident has had limited immediate impact on oil and natural gas supply
and prices because production has not been significantly disrupted.162 Longer-term impacts are
uncertain and depend at least in part on policy and regulatory responses, which may affect the
production of offshore oil and natural gas.
At the time of the incident, the oil and gas formation was still being explored, and was not yet in
the production phase of the project.163 Stopping production activity near the spill location for
safety reasons has so far resulted in a relatively small reduction in energy supply. MMS reported
that five offshore platforms were evacuated, halting—at least temporarily—approximately 2,300
barrels a day (0.14% of the Gulf’s oil production) and 1.2 million cubic feet of natural gas (0.02%
of the Gulf’s natural gas production).164
Further, currently high commercial oil inventories and the availability of the Strategic Petroleum
Reserve would likely help insulate the domestic oil market against short-term disruptions.165 After
the incident, the price for West Texas Intermediate crude oil fell as low as $64.78/barrel (May 25,
2010), versus $81.52/barrel on April 19, the day before the spill. Prices have recovered
somewhat, closing at $74.05/barrel on July 7, but remain below their level prior to the incident.166
Other oil market drivers softened prices, offsetting near-term support to prices from spill-related
uncertainty about adequate supply. Natural gas prices have climbed since the incident, from
$3.94/million btu to $4.57/million btu,167 but this too is likely primarily due to other drivers, such
as stronger weather-related natural gas demand in parts of the United States and concerns about
potential hurricane-related production disruptions in coming months.168
161 Prepared by Neelesh Nerurkar, Specialist in Energy Policy.
162 Energy Information Administration, U.S. Department of Energy, “Deepwater Horizon Oil Spill, This Week In
Petroleum,” Washington, DC, May 19, 2010, http://tonto.eia.doe.gov/oog/info/twip/twip.asp.
163 The Wall Street Journal citied an anonymous source who claimed that before the spill, BP had been days away from
announcing the discovery was “commercially attractive,” and that the Macondo Prospect held “tens of millions of
barrels” in potentially recoverable oil reserves (Russell Gold, Ben Casselman , and Guy Chazan, “Missing Workers
Feared Dead as Gulf Rig Sinks—One of the Industry’s Worst Disasters in Decades Occurred Days Before BP Was
Going to Disclose Significant Oil Find at Site,” Wall Street Journal, April 23, 2010). However, it would have taken
some years to develop the project into a producing facility.
164 See http://www.deepwaterhorizonresponse.com/go/doc/2931/550055/ .
165 Energy Information Administration, U.S. Department of Energy, “Deepwater Horizon Oil Spill,” This Week In
Petroleum, Washington, DC, May 19, 2010, http://tonto.eia.doe.gov/oog/info/twip/twiparch/100519/twipprint.html.
166 Energy Information Administration, U.S. Department of Energy, Petroleum Navigator, Washington, DC, July 8,
2010, http://www.eia.doe.gov/dnav/pet/pet_pri_spt_s1_d.htm.
167 Energy Information Administration, U.S. Department of Energy, Natural Gas Navigator, Washington, DC, June 15,
2010, http://www.eia.doe.gov/dnav/ng/hist/rngc1d.htm
168 Eileen Moustakis, “US Henry Hub gas at 4-mth high, other prices slip ,” Reuters, June 16, 2010.
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Longer-term impacts on U.S. oil production are uncertain and depend at least in part on the
response to the spill from Congress, federal regulators, and state governments. The Energy
Information Administration projects that the six-month moratorium on deepwater drilling
announced May 27 could reduce Gulf production by roughly 31,000 barrels per day in the fourth
quarter of 2010 and 82,000 barrels a day in 2011.169 Some experts suggest that reactions from
government and industry that limit investment or slow new project development could impact
potential domestic oil and natural gas production. Employment and taxes from the oil and gas
industry may be negatively impacted.170 Concerns about the environmental risks of offshore
drilling in the wake of the Deepwater Horizon incident may also affect how much acreage is
offered for offshore exploration and development in the future.
The longer-term impact on oil prices or U.S. oil imports is also uncertain. Any policy changes
that would affect U.S. oil supply would have to be factored into the context of the global oil
market, where oil prices are determined. U.S. offshore crude oil production in 2009 was 1.7
million barrels a day, of which 1.6 million barrels a day came from the U.S. section of the Gulf of
Mexico (including state and federal areas). This is about 2% of the roughly 84 million barrel-per-
day global oil market in 2009 (of which the United States consumed about 19 million barrels
daily).171 However, the Deepwater Horizon incident is also influencing policy and practices
abroad. Around 26 million barrels per day are produced offshore around the world.172 Regulators
and oil companies in other countries are likely to learn from this incident and make changes in
their offshore sectors as well, which could potentially impact a broader portion of global oil
supply and oil prices.
As with oil, measures affecting the pace, cost, and scope of offshore drilling can affect the supply
and price of natural gas. EIA projects that the six-month deepwater drilling moratorium could
reduce U.S. gas production by 0.05 billion cubic feet per day in the second half of 2010 and 0.25
billion cubic feet per day in 2011.173 Unlike the global oil market, natural gas markets are
generally more regional. (Global liquefied natural gas trade is growing and interlinking regions
but remains relatively small.) North America has a continent-wide market that is integrated
through a pipeline network connecting the lower 48 states, the most populous provinces of
Canada, and parts of Mexico.174 The United States produces 2.8 trillion cubic feet per year from
offshore sources, of which 2.7 trillion cubic feet come from the U.S. section of the offshore Gulf
of Mexico. The total North American natural gas market was 28.5 trillion cubic feet per day in
2008, of which U.S. consumption was 23.2 trillion cubic feet.175 Because U.S. offshore natural
gas supply has a higher share of a smaller market, there is potential for lower offshore supplies to
have a greater impact on U.S. natural gas prices than on oil prices. However, there are again a
169 Energy Information Administration, U.S. Department of Energy, Short-Term Energy Outlook, Washington, DC,
July 7, 2010, http://www.eia.doe.gov/emeu/steo/pub/contents.html.
170 Julie Wilson et al., Deepwater Horizon Tragedy: Near-Term and Long-Term Implications in the Gulf of Mexico,
Wood Mackenzie, Upstream Insights, Houston, TX, May 11, 2010.
171 Energy Information Administration, U.S. Department of Energy, http://www.eia.gov/oog/special/gulf/
gulf_fact_sheet.html?featureclicked=5& and http://www.eia.doe.gov/oil_gas/petroleum/info_glance/petroleum.html.
172 International Energy Agency, Monthly Oil Market Report, Paris, June 23, 2010
173 Energy Information Administration, Short-Term Energy Outlook, U.S. Department of Energy, Washington, DC,
July 7, 2010, http://www.eia.doe.gov/emeu/steo/pub/contents.html.
174 CRS Report R40487, Natural Gas Markets: An Overview of 2008, by Robert Pirog.
175 Energy Information Administration, U.S. Department of Energy, International Energy Statistics, Washington, DC,
http://tonto.eia.doe.gov/cfapps/ipdbproject/IEDIndex3.cfm.
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number of uncertainties involved, such as to what degree unconventional onshore natural gas
production can compensate for losses in offshore production.176
Possible Impacts on Shipping177
The Lower Mississippi River is one of the busiest waterways in the country in terms of
commercial ship traffic. Ports along the river serve as the major gateway for U.S. exports of
agricultural commodities, whose peak season generally begins in late summer, and imports of a
wide variety of commodities. During past oil spills, the Coast Guard has closed ports or severely
restricted ship traffic to prevent vessel traffic from spreading the oil. This oil spill has thus far not
affected ship traffic, as most of the oil has stayed east of the major shipping lanes. The Coast
Guard has set up cleaning stations at various points to clean hulls before vessels enter the river,
but only one ship has had to be cleaned so far.
Labor Issues178
National attention to the 11 worker fatalities is reflected in Congress’s interest in federal agency
jurisdiction over worker safety at oil drilling rigs on the OCS, and the prevalence of accidents,
injuries and fatalities at these locations.
Safety and Health of OCS Workers
The Occupational Safety and Health Act (OSH Act) provides for the establishment of workplace
safety standards for most private employers, including those that operate offshore oil and gas
facilities.179 Section 4(a) of the OSH Act indicates explicitly that the statute applies to
employment performed on OCS lands.180 Section 4(b)(1) of the OSH Act, however, clarifies that
the statute shall not apply when workplace safety standards have been established by other federal
agencies that have been granted the authority to promulgate such standards: “Nothing in this Act
shall apply to working conditions of employees with respect to which other Federal agencies ...
exercise statutory authority to prescribe or enforce standards or regulations affecting occupational
safety or health.”181
In two sections of the Outer Continental Shelf Lands Act (OCSLA), the “Secretary of the
Department in which the Coast Guard is operating” (e.g., the Secretary of the Department of
Homeland Security) has been authorized to promulgate regulations or standards involving
workplace safety. Section 4(d)(1) authorizes the Secretary to promulgate and enforce regulations
with respect to lights and other warning devices, safety equipment, and “other matters relating to
the promotion of safety of life and property on the artificial islands, installations, and other
176 For further reading on offshore production and oil and natural gas prices, see CRS Report R40645, U.S. Offshore
Oil and Gas Resources: Prospects and Processes, by Marc Humphries, Robert Pirog, and Gene Whitney.
177 Prepared by John Frittelli, Specialist in Transportation Policy.
178 Prepared by Linda Levine, Specialist in Labor Economics.
179 29 U.S.C. § 651 et seq.
180 29 U.S.C. § 653(a).
181 29 U.S.C. § 653(b)(1).
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devices” attached to the seabed of the OCS or on adjacent waters.182 In addition, Section 21(c)
authorizes the Secretary to promulgate regulations or standards “applying to unregulated
hazardous working conditions related to activities on the outer Continental Shelf when he
determines such regulations or standards are necessary.”183
In 1979, the Coast Guard and the Occupational Safety and Health Administration (OSHA) signed
a memorandum of understanding (MOU) to establish procedures for increasing consultation and
coordination between the two agencies.184 The MOU appears to elaborate on the relationship
between the Coast Guard and OSHA in light of the authority granted by the OCSLA:
The Coast Guard will develop and promulgate necessary regulations to assure safe and healthful
working conditions on the OCS. OSHA will continue to promulgate general standards, which
may apply to working conditions on the OCS not being regulated by the Coast Guard. In
developing regulations and standards, the two agencies will cooperate to the maximum extent
possible.185
Since the signing of the MOU, the Coast Guard has issued various regulations with regard to
OCS activities.186 Part 142 of Title 33, Code of Federal Regulations, includes regulations relating
to workplace safety and health on the OCS.
DOI is also involved in workplace safety. Under Section 22(a) of the OCSLA, the Secretary of
the Interior, the Secretary of Homeland Security, and the Secretary of the Army are authorized to
enforce safety and environmental regulations promulgated pursuant to the statute.187 Regulations
that address the inspection of OCS facilities have been issued by the Coast Guard. Section
140.101(b) of Title 33, Code of Federal Regulations, states: “On behalf of the Coast Guard, each
fixed OCS facility engaged in OCS activities is subject to inspection by the Minerals
Management Service (MMS).”188
Oil and Gas Industry Safety Statistics189
Data from the U.S. Bureau of Labor Statistics’ (BLS’s) Census of Fatal Occupational Injuries
(CFO) indicates that, in 2008, the latest year for which CFO data are available, 18 of the 174
fatalities at all U.S. workplaces that resulted from fires and explosions occurred in the oil and gas
industry. The oil and gas industry is defined in the CFO to include oil and gas extraction (NAICS
211), contract drilling of oil and gas wells (NAICS 213111), and support activities for oil and gas
182 43 U.S.C. § 1333(d)(1).
183 43 U.S.C. § 1347(c).
184 Memorandum of Understanding Between the U.S. Coast Guard and OSHA Concerning Occupational Safety and
Health on the Outer Continental Shelf (OCS) (December 19, 1979), available at http://www.osha.gov/pls/oshaweb/
owadisp.show_document?p_table=MOU&p_id=223.
185 Ibid.
186 See 33 C.F.R. subchapter N.
187 43 U.S.C. § 1348(a).
188 On May 19, 2010, the Secretary of the Interior issued Order No. 3299, which reassigned the safety and
environmental enforcement functions of the Minerals Management Service to a new Bureau of Safety and
Environmental Enforcement. See U.S. Dept. of the Interior, Order No. 3299, available at http://www.mms.gov/ooc/
pdfs/DOI_pressrelease/SecretaryOrder3299.pdf.
189 Prepared by Linda Levine, Specialist in Labor Economics.
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operations (NAICS 213112), and includes both onshore and offshore activities.190 Data are not
currently available for offshore operations alone. Of the 18 deaths reported, 11 (61%) occurred at
firms performing support activities for oil and gas operations; 4 (22%) at establishments engaged
in oil and gas extraction; and 3 (17%) at contract oil and gas well drillers. Looked at in a different
way, it appears that 15%, or 18, of the oil and gas extraction industry’s 120 fatalities in 2008 were
due to fires and explosions. Among the 120 deaths, almost three out of five (69) took place in the
support activities for oil and gas operations industry. Another one out of four (30) fatalities were
in the contract oil and gas well drilling industry. Fewer than one in five (21) fatalities caused by
fire and explosions took place in the oil and gas extraction industry.191
Injury rates in two of the three industries were below average in 2007, according BLS’s annual
Survey of Occupational Injuries and Illnesses.192 In 2007, when there were 4.0 cases of nonfatal
injuries per 100 full-time workers, the injury rate in the oil and gas extraction industry was 1.6; in
support activities for oil and gas operations, it was 2.6. In contrast, the injury rate among contract
oil and gas drillers was 4.5 cases per 100 full-time workers. 193 With regard specifically to injuries
and illnesses associated with fires and explosions, there were 1,870 such cases in 2007, of which
50 occurred in the oil and gas extraction industry; the other two industries had no reported
cases.194
The Minerals Management Service (MMS) requires firms operating on the Outer Continental
Shelf (OCS) to report on the occurrence of unsafe incidents. Firms must report on incidents
involving fatalities; injuries that require evacuation of persons for medical treatment or that result
in one or more days away from work, restricted work, or job transfers; fires and explosions; and
uncontrolled flows, among other types of incidents. In 2009, according to BOEMRE/MMS’s
database, there were four incidents on facilities in the Gulf of Mexico associated with deaths.
There were 290 incidents in the Gulf and 16 in the Pacific OCS region linked to injuries. The 145
incidents of fires/explosions reported to the MMS in 2009 may or may not have caused fatalities
or injuries.195
190 NAICS stands for the North American Industry Classification System, which federal statistical agencies use to
categorize establishments into industries. Establishments primarily engaged in oil and gas extraction as well as those
chiefly providing support services for oil and gas operations are categorized in the mining sector (NAICS 21). The oil
and gas extraction subsector (NAICS 211) includes firms that explore, develop, and produce oil or gas wells that they
operate for themselves or under contract to others. The support activities for mining subsector (NAICS 213) includes
companies that primarily drill oil and gas wells for others on a contract or fee basis (NAICS 213111) and perform other
support services on a contract or fee basis for oil and gas operations (NAICS 213112) such as cementing and shooting
wells.
191 CFO data at http://stats.bls.gov/iif/oshwc/cfoi/cftb0232.pdf.
192 Data are from 2007 because statistics are not available separately in 2008 for the oil and gas drilling industry.
193 The Survey of Occupational Injuries and Illnesses’ data chiefly is from the occupational safety and health logs that
OSHA requires employers to maintain. Total recordable cases are the sum of cases with days away from work, job
transfer, or restriction and other cases. Survey of Occupational Injuries and Illnesses data at http://stats.bls.gov/iif/
oshwc/osh/os/ostb1909.pdf.
194 These cases are limited to those involving days away from work, which are regarded as the most serious nonfatal
injuries and illnesses. Survey of Occupational Injuries and Illnesses data at http://stats.bls.gov/iif/oshwc/osh/case/
ostb1946.pdf.
195 MMS incident statistics at http://www.mms.gov/incidents/IncidentStatisticsSummaries.htm.
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Coast Guard Oversight of OCS Safety196
Technical Competence
The Coast Guard’s technical expertise in providing effective safety oversight of certain maritime
operations has been a recent congressional concern.197 Some have asserted that the Coast Guard’s
practice of regularly rotating staff geographically or by activity, as military organizations
typically do, has hindered the agency’s ability to develop a cadre of staff with the technical
expertise that certain segments of the maritime industry require. The offshore industry appears to
be one of those segments. In addition to moving farther from shore and into deeper water, this
industry is designing new “hybrid systems” with “novel configurations” that no longer fit into a
single vessel category, requiring the classification societies to amend their rules.198 Some have
suggested that a separate, civilian agency be created to oversee maritime safety matters. The
Coast Guard recently revamped its safety program. Among other things, it created additional
civilian safety positions, converted military positions into civilian ones, and developed a long-
term career path for civilian safety inspectors and investigators.
Regulatory Issues
In testimony before the Coast Guard and MMS joint investigation hearing, a Coast Guard official
from the local district that oversees the Gulf of Mexico testified that “regulations governing Coast
Guard inspections of mobile drilling rigs date to 1978” and that the regulations do not cover some
rig equipment because that equipment was not in use when these regulations were written.199
Some of the regulatory sections specific to MODUs in 46 C.F.R. Parts 107-109 cite a rulemaking
from 1978. In 1999, the Coast Guard issued a notice of proposed rulemaking (NPRM) regarding
updating regulations under 33 C.F.R. Parts 140-147, which implement the Coast Guard’s
authority under OCSLA. In this NPRM, the Coast Guard stated that the last major revision of
these regulations had occurred in 1982 and noted that offshore facilities had moved much farther
offshore (127 miles) and into much deeper water (7,500 feet) since then, and therefore it needed
to update its safety regulations.200 The Coast Guard also stated that one intent in updating the
regulations was to align the requirements of foreign OCS units with those of U.S. OCS units, and
it indicated that dramatic changes to the nature of the work and the technology used in OCS units
had made its current regulations deficient. The comment period has been repeatedly extended.
The Coast Guard plans on issuing a supplemental notice of proposed rulemaking on OCS
activities in November 2010.201
The foreign flagging of the Deepwater Horizon is an issue raised by some Members of Congress,
who cite safety concerns, among other reasons, for their preference for U.S. flagging of offshore
196 Prepared by John Frittelli, Specialist in Transportation Policy.
197 House Committee on Transportation and Infrastructure, Subcommittee on Coast Guard and Maritime
Transportation, Hearing on Challenges Facing the Coast Guard’s Marine Safety Program, July 27, 2007.
198 “Hurricane Lessons Bring New Rules, Floating System Designs,” Offshore, June 2007, pp. 84-87.
199 Brett Clanton, “Federal Testing of Rigs Can Have Limits,” Houston Chronicle, May 13, 2010. The website of the
joint investigation states that transcripts of hearing testimony will not be available until January 2011;
http://www.deepwaterinvestigation.com/go/page/3043/46731/
200 64 Fed. Reg. 68416, December 7, 1999. Comments can be viewed under ID # USCG-1998-3868 at
http://www.regulations.gov.
201 OMB, Spring 2010 Unified Agenda, RIN: 1625-AA18.
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rigs.202 The Coast Guard contends that foreign-flagged and U.S.-flagged rigs are held to the same
level of safety oversight.203 While substantively equivalent, the Coast Guard relies more on
classification societies (see “Classification Societies” section) to perform inspections in the case
of foreign-flagged rigs than it does for U.S.-flagged rigs.204 In the past, lower safety standards
were associated with “flag of convenience” (FOC) ships, but long-established FOC countries
have raised their standards. IMO conventions and better enforcement by coastal states that share
the results of boarding inspections are also credited with raising standards. The Coast Guard has
included the Marshall Islands (the flag state of the Deepwater Horizon) as one of 16 flag states it
recognizes as having high standards based on the results of its boarding inspections.205 This list,
as well as the Coast Guard’s list of the 20 worst performers,206 is roughly evenly divided between
FOC countries and traditional maritime powers, suggesting that FOC designation in and of itself
is not an indicator of safety performance. As mentioned earlier, the Coast Guard, the flag state,
IMO conventions, and classification societies are primarily concerned with the seaworthiness of a
floating rig, not the drilling aspects of a rig.
IMO Convention Issues
In addition to the IMO MODU code, other IMO conventions have at least some applicability to
foreign-flagged offshore drilling rigs. The International Convention on Oil Pollution
Preparedness, Response and Co-operation, 1990 (OPRC 1990), requires that both fixed and
floating structures engaged in exploration, production, loading, and unloading of oil (in addition
to ships more generally) prepare oil pollution emergency response plans.207 This convention
contains very specific and detailed provisions that one observer describes as “probably the most
important international legal document that regulates pollution of the marine environment
resulting from offshore oil and gas activities.”208 Other IMO conventions, while providing a
comprehensive set of detailed and specific safety and pollution prevention requirements for ships,
either do not mention oil rigs or mention them only briefly and under vague pronouncements.209
Congress might consider whether a comprehensive international regime is warranted, considering
plans for oil exploration in especially life-threatening and environmentally sensitive areas like the
Arctic. While drafts of conventions have been issued and other nations support a comprehensive
IMO regime for oil rigs, the United States is opposed.210 It can be argued that the IMO, whose
202 U.S. Congress, House Committee on Transportation and Infrastructure, Subcommittee on Coast Guard and Maritime
Transportation, Foreign Vessel Operations in the U.S. Exclusive Economic Zone, 111th Cong., June 16, 2010.
203 Oral and written testimony of Kevin Cook, USCG Director of Prevention Policy, U.S. Congress, House Committee
on Transportation and Infrastructure, Subcommittee on Coast Guard and Maritime Transportation, Foreign Vessel
Operations in the U.S. Exclusive Economic Zone, 111th Cong., June 16, 2010.
204 Ibid.
205 The Coast Guard’s “Qualship 21 Initiative.”
206 The Coast Guard’s “Annual Targeted Flag List.”
207 The United States is a party to this convention.
208 Hossein Esmaeili, The Legal Regime of Offshore Oil Rigs in International Law, Ashgate Dartmouth, Aldershot, UK,
2001, pp. 157-158.
209 The only other detailed conventions regarding offshore rigs is one seeking to prevent ships from colliding with them
and one to prevent terrorist acts against them.
210 Mikhail Kashubsky, “Marine Pollution from the Offshore Oil and Gas Industry: Review of Major Conventions and
Russian Law (Part 1), Maritime Studies, November-December 2006, pp. 6 and 8, at
http://www.customscentre.canberra.edu.au/librarymanager/libs/17/Marine_Pollution_part1.pdf.
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primary concern has been cargo and cruise ships, does not have the expertise to prescribe
technical standards for offshore oil rigs.211 Detailed standards do exist on a regional basis
(examples include the Mediterranean Sea, the Baltic Sea, and the Persian Gulf), and one could
argue that different environments dictate different requirements.212 However, the global nature of
the oil industry raises the question of whether an international convention on offshore rigs of all
types would enhance their safety.
DOI Initiative to Reorganize MMS213
Congress has expressed concern that the numerous aspects of OCS management responsibility,
specifically tasks to manage both the operational aspects and the revenue aspects of the leasing
program, may be a source of conflicts of interest within MMS. To address claims that the current
organization of MMS fosters systemic weaknesses in MMS regulatory actions, Secretary Salazar
issued a secretarial order on May 19, 2010, establishing three new organizational units within the
Department of the Interior and redelegating the functions of MMS to these new entities.
In general, agency heads have implied authority to organize and manage the agencies and
departments they head.214 In addition, since the 1950s, the powers, duties, and functions of the
component offices of most agencies have been vested in the agency head, who is, in turn,
empowered to delegate these powers, duties, and authorities. Furthermore, Section 301 of Title 5
of the U.S. Code provides that the “head of an Executive department or military department may
prescribe regulations for the government of his department, the conduct of its employees, the
distribution and performance of its business.” The agency head’s authority does not, however,
supersede congressional authority to provide for specific organizational arrangements or to vest
powers, duties, or authorities in particular offices established in this way.215
Reorganization Authority of the Secretary of the Interior
Reorganization Plan No. 3 of 1950 provided that, except with regard to the functions vested by
the Administrative Procedure Act in hearing examiners and the functions of the Virgin Islands
Corporation or of its board of directors or officers, functions that had previously been vested in
the heads of DOI’s component entities were transferred to the Secretary of the Interior, thus
centralizing authority over the department.216 The Secretary was also authorized, by the
211 Canadian Maritime Law Association, “Discussion Paper on the Need for an International Legal Regime for
Offshore Units, Artificial Islands and Related Structures Used in Exploration for and Exploitation of Petroleum and
Seabed Resources, 1996, at http://www.cmla.org/papers/MAR96.htm.
212 Maria Gavouneli, Pollution from Offshore Installations (London: Graham and Trotman Ltd., 1995).
213 Prepared by Henry B. Hogue, Analyst in American National Government.
214 See Basil J. Mezines, Jacob A. Stein, and Jules Gruff, Administrative Law, vol. 1 (New York: Matthew Bender,
2006), pp. 4-18 to 4-27.
215 In Myers v. United States, 272 U.S. 52, 129 (1926), the Supreme Court declared: “[t]o Congress under its legislative
power is given the establishment of offices, the determination of their functions and jurisdiction....” Subsequent to the
decision in Myers, the Court has consistently recognized the authority of Congress to create and abolish offices within
the executive branch, to the extent that it is generally considered settled that the transfer or abolition of statutorily
vested functions may only be accomplished pursuant to congressional authorization. See, e.g., Buckley v. Valeo, 424
U.S. 1, 138 (1976); INS v. Chadha, 462 U.S. 919, 954 (1983).
216 43 U.S.C. § 1451, note.
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reorganization plan, to redelegate these functions to any department agency, employee, or officer,
unless otherwise prevented by law from doing so.
Establishment of the Minerals Management Service
MMS was established administratively by Secretary of the Interior James Watt in 1982. A series
of secretarial orders established the unit and transferred certain functions to it from other
organizational units within DOI.217 Congress appropriated funds for this new entity for the
following fiscal year.218 The conference report did not specifically address the reorganization, but
the House report stated, with reference to MMS, the following:
This organization was established by Secretarial Order 3071 which transferred resources from the
Geological Survey, the Bureau of Land Management, and the Office of the Secretary. The
reorganization was the result of the underreporting of oil and gas production from Federal and
Indian lands, theft of oil from those lands, and underpayment and inadequate collection of
royalties owed to the United States.... The bulk of the appropriation ... is associated with the
Outer Continental Shelf Leasing program, evaluation of resources, regulations, and activities
associated with Federal and Indian lands. These are functions formerly divided between the
Geological Survey and the Bureau of Land Management. That division of function often caused
problems of neglect, duplication, and turf wars. The Committee agrees with the consolidation.
This consolidation places the responsibility and accountability for the off-shore mineral leasing
program in one spot, thus making oversight easier. The Committee will be looking carefully at
the progress this organization makes to make sure that the people of the United States get the
maximum protection of their resources, including a proper return on their ownership.219
Organizationally, MMS has been located under the Assistant Secretary for Land and Minerals
Management. The leaders of the Bureau of Land Management and the Office of Surface Mining
Reclamation and Enforcement also report to this assistant secretary. Whereas these two leaders
are appointed by the President, by and with the advice and consent of the Senate, MMS has been
led by a director who is appointed by the Secretary. The MMS directorship has been a non-career
(political) Senior Executive Service (SES) position.
Redelegation of Minerals Management Service Functions
It could be argued that the numerous aspects of OCS management responsibility, specifically
tasks to manage both the operational aspects and the revenue aspects of the leasing program, have
been a source of conflicts of interest within MMS. It could be claimed, in other words, that the
organization of MMS has fostered systemic weaknesses in MMS decision-making. To the degree
that such deficiencies have existed, they might be addressed through a reorganization that
separates incompatible functions and vests them in different entities that are independent from
one another, either within DOI or in different parts of the federal government.
217 The organization and functions of the Minerals Management Service are identified in Part 118 of the Department of
the Interior Departmental Manual, available at http://elips.doi.gov/app_DM/index.cfm?fuseaction=home.
218 P.L. 97-394, 96 Stat. 1973.
219 U.S. Congress, House Committee on Appropriations, Department of the Interior and Related Agencies
Appropriation Bill, 1983, report to accompany H.R. 7356, 97th Cong., 2nd sess. (Washington: GPO, 1982), p. 40.
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On May 13, 2010, the Department of the Interior announced that Secretary Salazar had initiated
the process of reorganizing the Minerals Management Service administratively.220 The
announcement indicated that the reorganization would be overseen by Assistant Secretary for
Policy, Management, and Budget Rhea Suh and Senior Advisor Chris Henderson. The Secretary
reportedly sent a letter to congressional leaders seeking input on the reorganization. The
prospective organizational changes were to “achieve the following principles: Independent safety
enforcement function; Full enforcement authority; Priority attention to safety and environmental
values; and Application of best technology and cutting edge science.”221
On May 19, 2010, Secretary Salazar issued Order No. 3299, which divided MMS into three new
offices. Under the provisions of the order, two of these new organizations, the Bureau of Ocean
Energy Management and the Bureau of Safety and Environmental Enforcement, will be
organizationally housed under the Assistant Secretary for Land and Minerals Management, which
has been the location of MMS. The third unit, the Office of Natural Resources Revenue, will be
under the Assistant Secretary for Policy, Management, and Budget.
According to the order, the Bureau of Ocean Energy Management will “exercise the conventional
(e.g., oil and gas) and renewable energy-related management functions of [MMS] not otherwise
transferred [by the order] including ... activities involving resource evaluation, planning, and
leasing.”
The Bureau of Safety and Environmental Enforcement will carry out the functions of MMS
related to safety and environmental enforcement, including “the authority to inspect, investigate,
summon witnesses and produce evidence, levy penalties, cancel or suspend activities, and oversee
safety, response, and removal preparedness.”
The Office of Natural Resources Revenue will be responsible for royalty and revenue
management functions of MMS, including “royalty and revenue collection, distribution, auditing
and compliance, investigation and enforcement, and asset management for both onshore and
offshore activities.”
The order also provides that the two Assistant Secretaries mentioned above will “ensure that this
reorganization will provide that agency decisions are made in compliance with all applicable
safety, environmental, and conservation laws and regulations, and that all reviews and
consultations are conducted in an independent, comprehensive, and scientifically-sound manner.”
The two Assistant Secretaries are charged with developing the implementation details and
reporting those details to the Secretary. They are to “develop a schedule within [30] days for the
implementation” of the order in consultation with the Office of Management and Budget and
relevant congressional committees.
Secretary Salazar has also called for Congress to enact organic legislation for MMS. During his
testimony before the Senate Committee on Energy and Natural Resources, the day before he
issued the reorganization order, Salazar stated:
220 U.S. Department of the Interior, “Salazar Names Senior Interior Officials to Lead Minerals Management Service
Restructuring,” press release, May 13, 2010, http://www.doi.gov/news/pressreleases/Salazar-Names-Senior-Interior-
Officials-to-Lead-Minerals-Management-Service-Restructuring.cfm#.
221 Ibid.
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[T]he Department of Interior has its responsibility. But I would say this Congress also has its
responsibility. And I was proud to be a member of the Senate with, I think, everyone who is
currently sitting in this committee today. From this Congress I would expect that we would move
forward, and we would see thoughtfully crafted, organic legislation for the Minerals Management
Service. Some of you, Senator Wyden, have pushed that effort for a while. I have supported that
effort. It should be something that gets done. An agency the size of the Minerals Management
Service that collects, on average, $13 billion a year, that has these responsibilities for the Outer
Continental Shelf in terms of the energy production and future of the United States of America,
should not exist by fiat of a secretarial order that was signed almost 30 years ago. It is important
that there be thoughtfully crafted, organic legislation for the new agency to be created. I will do—
I will continue to do the efforts that I can do within the authority that I have as secretary to redo
the Minerals Management Service. But at the end of the day, it’s going to be important that
Congress take up that responsibility.222
Other Congressional Activity Related to Agency Reorganization
Constitutionally, the establishment, organization, and reorganization of governmental entities is
the province of Congress. Congress, through law, determines the need for, creates, and locates
offices; establishes their missions, powers, duties, and functions; defines the parameters of
personnel systems; confirms certain executive officials; provides funding; and ultimately
evaluates whether a government unit shall continue in existence. In exercising this authority,
Congress has sometimes changed organizational arrangements by enacting new statutes, and at
other times has delegated reorganization authority to the President or to agency heads.
Congress might elect to establish the previous or new DOI organizational arrangements in statute,
or to establish some other entity or entities that would carry out the functions previously vested in
MMS. Such an reorganization by statute could differ from the administrative reorganization
carried out by the Secretary in several ways. First, whereas the Secretary’s order redelegates
functions and resources within DOI, Congress might elect to redelegate functions and resources
among DOI and other federal agencies. Second, if Congress were to establish existing or new
organizational arrangements in statute, these arrangements would not be subject to further
reorganization by this Secretary or a future Secretary, unless otherwise specified in statute. Third,
Congress might elect to establish leadership positions for the associated entities that would be
subject to the advice and consent of the Senate. Absent the establishment of such requirements,
these leaders would be appointed by the Secretary, without formal congressional involvement.
When an agency head has reorganized a portion of his or her agency administratively, Congress
has, on occasion, endorsed the action without giving it statutory underpinnings. For example,
Congress has sometimes validated an agency reorganization through the appropriations process,
by adjusting the agency’s appropriation to match the new configuration or by addressing the
action in the conference report.223 Similarly, Congress has recognized some newly created entities
222 U.S. Congress, Senate Committee on Energy and Natural Resources, hearing on issues involving offshore oil and
gas exploration including the Deepwater Horizon accident, 111th Cong., 2nd sess., May 18, 2010, archive webcast
available at http://energy.senate.gov/public/index.cfm?Fuseaction=Hearings.LiveStream&Hearing_id=69f3a508-9c1a-
a3d4-ffa5-fd397b02c93b. Excerpted comments at approximately 35:30.
223 U.S. Government Accountability Office, Principles of Federal Appropriations Law, Third Edition Volume I, GAO-
04-261SP (Washington: January 2004), pp. 2-61 through 2-65. This report summarizes the principles to be applied in
this situation by quoting a Comptroller General’s opinion as follows: “‘To conclude that Congress through the
appropriations process has ratified agency action, three factors generally must be present. First, the agency takes the
action pursuant to at least arguable authority; second, the Congress has specific knowledge of the facts; and third, the
(continued...)
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by delegating to them specific authorities, or otherwise making reference to them in statute. Of
course, Congress can also register its disapproval of a reorganization by appropriating little or no
funding for a new entity, by condemning the action in conference report language, or by
redelegating authority to competing organizations.
Legislation Related to Agency Reorganization
During the 111th Congress, prior to the Deepwater Horizon oil spill, bills were introduced that
would reorganize MMS and its functions. On September 9, 2009, Representative Nick J. Rahall
introduced H.R. 3534, the Consolidated Land, Energy, and Aquatic Resources Act of 2009. This
bill would, among other effects, establish in DOI an Office of Federal Energy and Minerals
Leasing. The bill would transfer to this new office certain functions of MMS as well as the Oil
and Gas Management program of the Bureau of Land Management.
On October 7, 2009, Representative Darrell E. Issa introduced H.R. 3736, the Minerals
Management Service Reform Act. This bill would establish MMS as an independent
establishment in the executive branch, outside of the Department of the Interior. It would vest in
the MMS Director all powers and duties of the present MMS as well as all functions, powers, and
duties that have been vested in DOI relating to bidding, leasing, and managing all offshore oil and
gas, including with respect to the Gulf of Mexico and other areas of the outer continental shelf;
and collection of revenue (other than taxes) generated by such oil and gas.
Each of these bills would establish the head of the new entity as a position filled through
appointment by the President with the advice and consent of the Senate.
FEMA Issues224
The Robert T. Stafford Disaster Relief and Emergency Assistance Act (referred to as the Stafford
Act, 42 U.S.C. 5721 et seq.) authorizes the President to issue “major disaster” or “emergency”
declarations before or after catastrophes occur. The Gulf Coast oil spill is currently being
addressed by a law fashioned for that purpose, the Oil Pollution Act of 1990 (OPA), P.L. 101-
380.225 When certain events occur that carry with them such specific response authorities as
pertain to oil spills or plane crashes, the President generally does not use his authority to issue a
declaration and activate FEMA’s authorities. Given the current circumstance of the OPA authority
being in place and the existence of the Oil Spill Liability Trust Fund, FEMA has been playing an
auxiliary role. It includes assisting the lead agency in the response, the U.S. Coast Guard (like
FEMA, an entity within the Department of Homeland Security), in staffing and related support
areas. If some factors change, such as the scope of the impact on the coastal states, or the need to
provide supplemental federal funding, FEMA’s role could expand. In that event, the Stafford Act,
(...continued)
appropriation of funds clearly bestows the claimed authority’” (p. 2-65).
224 Prepared by Fran McCarthy, Analyst in Emergency Management Policy. For additional information, see CRS
Report R41234, Potential Stafford Act Declarations for the Gulf Coast Oil Spill: Issues for Congress, by Francis X.
McCarthy.
225 For a detailed discussion of the OPA, see CRS Report RL33705, Oil Spills in U.S. Coastal Waters: Background,
Governance, and Issues for Congress, by Jonathan L. Ramseur.
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P.L. 93-288, would present several options, and could provide a number of programs, to address
the oil spill.
An emergency declaration under the Stafford Act is a potential approach to the current situation
since it is intended to lessen the impact of an imminent disaster. Another option is a major disaster
declaration, which would open up more Stafford Act programs that might be appropriate for the
needs generated by the spill.226
Federal Duplication/Federal Coordination
FEMA assistance can be rapid and flexible, but it also would need to be carefully delineated to
avoid duplication of benefits and general confusion when working in conjunction with P.L. 101-
380. Under that law, which provides both authorities and a fund for compensation, the incident is
currently being addressed and the federal response coordinated. FEMA and other federal agencies
are now seeking to maintain a delicate balance as they begin to coordinate assistance for small
businesses and social services. It appears that the federal government is attempting to accomplish
the provision of assistance, and a structure for response and recovery, without formally declaring
an emergency or a disaster. The Obama Administration announced that FEMA will establish a
task force by May 27, 2010, to develop a Social Services and Small Businesses Coordination
Plan. As an Office of Management and Budget memorandum explains:
The plan is not intended to disrupt ongoing, day-to-day communications between operational
agencies and their State, local and tribal partners. Rather, it will be a critical and timely resource
to these partners to help provide a rapid Federal response to the evolving situation and to
reinforce the cooperation of the responsible parties. This effort to ensure more seamless delivery
of claims and benefits to individuals and small businesses is an important step of the
administration’s response to the oil spill. Further steps include anticipating and preparing for the
post-incident recovery needs of the Gulf Coast. 227
The reluctance to use the presidential authority for a disaster declaration is understandable given
the existing authorities and the desire not only to allow the OPA to work but also to maintain
public pressure on the “responsible parties” to pay for the costs of the oil spill. It is not clear if the
intent is to move the coordination work forward and later seek compensation from the responsible
parties, or if this work is assumed to be a relatively low-cost task that will not require the
statutory authority of the Stafford Act or the financial resources of the President’s Disaster Relief
Fund.
Exxon Valdez
During the previous large spill, the Exxon Valdez spill in 1989, President George H. W. Bush
turned down the governor of Alaska’s two requests for an emergency declaration. The rationale
for the turndowns was that a declaration by the President would hinder the government’s
litigation against Exxon that promised substantial compensation for the incident. One FEMA
attorney from that period offered an explanation for the turndown:
226 For more information on the declarations process, see CRS Report RL34146, FEMA’s Disaster Declaration
Process: A Primer, by Francis X. McCarthy.
227 Jason Miller, “Feds to help small businesses affected by oil spill,” Federal News Radio, May 18, 2010,
http://www.federalnewsradio.com/?nid=35&sid=1959850.
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The Department of Justice opposed a declaration of disaster by then-President George H. W.
Bush on the basis that it might impact adversely the case of the United States against Exxon.
When asked at a Senate Appropriations Committee hearing by Senator Ted Stevens (R-Alaska)
why no declaration of disaster had occurred, the then-Acting General Counsel of FEMA, George
Watson, said on the record that he had issued a legal opinion stating that no declaration of an oil
spill could be made under the Stafford Act.
When Sen. Stevens asked for a copy of the opinion, Mr. Watson said he would furnish one.
Instead of an opinion, a somewhat garbled statement was given by FEMA’s congressional liaison
for insertion in the record. The statement basically concluded that where a parallel statutory
scheme offered both compensation and better litigation rights to the United States than the
Stafford Act, then the president would not declare a disaster or emergency.228
FEMA’s position or interpretation may be defensible because the Exxon Valdez shipwreck that
resulted in the oil spill arguably did not constitute a major disaster as defined in the Stafford Act.
However, the current situation on the Gulf Coast caused by the explosion on the Deepwater
Horizon drilling platform arguably may fall within the Stafford Act statutory language. Section
102 of the act defines a disaster in part as
any fire, flood, or explosion, in any part of the United States, which in the determination of
the President causes damage of sufficient severity and magnitude to warrant major disaster
assistance under this Act to supplement the efforts and available resources of states, local
governments, and disaster relief organizations in alleviating the damage, loss, hardship, or
suffering caused thereby.229
Recent Regional Disaster History
Using a Stafford Act emergency or major disaster declaration for the Gulf Coast oil spill, for Gulf
Coast states that are now approaching the fifth anniversary of the Hurricane Katrina landfall,
could remind them of difficult, lingering issues from that disaster in 2005. A declaration could
also, however, present a second chance for long-term recovery assistance to that region,
administered by new leadership at DHS and FEMA.
Managing public expectations is difficult even in the smallest disaster event. Working with a
region that is aware of the potential aid under Stafford and mistrustful of its delivery would be a
hard challenge. FEMA’s attempt to work in coordination with another set of authorities being
carried out by other agencies and departments would only add to the complexity.
It could be argued that the absence of increased federal involvement could serve to simplify the
response. At least one area, long-term recovery, is not directly addressed in P.L. 101-380. Some
might argue that it is also an area the federal government did not address in the aftermath of
Katrina. At congressional direction, FEMA has published a draft National Disaster Recovery
Framework.230 Perhaps amidst the current complications of overlapping authorities and funds,
228 William R. Cumming, Letter to the Editor, Natural Hazards Observer, January 2009, http://www.colorado.edu/
hazards/o/archives/2009/jaan_observerweb.pdf.
229 42 U.S.C. 5122.
230 DHS/FEMA, “National Disaster Recovery Framework—Draft”, February 10, 2010,
http://www.disasterrecoveryworkinggroup.gov/ndrf.pdf.
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implementing that framework could provide a viable and limited option for the use of Stafford
Act authorities.
Others might argue that a smaller role for the federal government might be the correct role, to
encourage local initiative, private-sector renewal, and continuing involvement by the “responsible
parties.” Within the context of a general distrust of government activity, possibly accentuated in
the Gulf region, as well as the current strains on the Disaster Relief Fund, perhaps less
government involvement and a lower federal profile would be a preferable option for the region’s
recovery.231
Conclusion
The Deepwater Horizon explosion and oil spill have set in motion a series of questions and
concerns about oil exploration and recovery in the Gulf of Mexico generally, about the federal
offshore oil and gas program, and about the risks of deepwater drilling in particular. The incident
has raised many issues; this report provides a set of selected descriptions to give the reader a
baseline and context for pursuing topics of interest.
Several themes trace through the diverse aspects of the incident:
• The explosion and oil spill having occurred, what lessons should be drawn from
the incident? Such lessons may involve the appropriateness and capabilities of
the technologies used in drilling and in trying to stop the spill; the adequacy of
the regulatory regime and how it was administered and enforced; possible
implications of corporate cultures of the companies involved; and the adequacy
of cleanup technologies and of the safety net for impacted businesses and
communities.
• As oil and gas exploration and recovery moved into the deepwater frontier, were
technologies and regulatory capacities keeping pace with new and/or heightened
risks? Technologies and regulations appropriate to onshore and shallow-water
exploration and recovery may not be adequate to address risks in deep water.
There are economic incentives to develop technologies to find and recover
deepwater oil and gas, but the question arises of whether concomitant incentives
exist to ensure that those technologies are robust enough to provide a reasonable
margin of safety in this more challenging environment. Likewise, it might be
asked if administrative and regulatory requirements appropriate to the less-
challenging onshore and shallow-water environments have been, or need to be,
strengthened to address deepwater risks.
• What interventions may be necessary to ensure recovery of Gulf resources and
amenities? The spilled oil will surely degrade over time; intervention might
accelerate cleanup, but may have its own costs.
231 For more information on the Disaster Relief Fund, see CRS Report R40708, Disaster Relief Funding and
Emergency Supplemental Appropriations, by Bruce R. Lindsay and Justin Murray.
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• What does the Deepwater Horizon incident imply for national energy policy, and
the tradeoffs between energy needs, risks of deepwater drilling, and protection of
natural resources and amenities?
Diverse stakeholders will find different lessons in the Deepwater Horizon incident. Some will
focus on the risks to the environment and the economic impacts on fishermen and communities;
others will focus on the value of the oil that fuels the U.S. economy. Some will find the risks
unacceptable; others will say that the risks can be overcome. In the end, the focal issue may be
the management of risk: even with robust efforts to prevent oil-related incidents, they can and
will happen—at which point the crucial question is how well prepared one is to cope with the
consequences.
Author Contact Information
Curry L. Hagerty, Coordinator
James E. Nichols
Specialist in Energy and Natural Resources Policy
Law Clerk
chagerty@crs.loc.gov, 7-7738
jnichols@crs.loc.gov, 7-5812
Jonathan L. Ramseur, Coordinator
Linda Levine
Specialist in Environmental Policy
Specialist in Labor Economics
jramseur@crs.loc.gov, 7-7919
llevine@crs.loc.gov, 7-7756
Peter Folger
John Frittelli
Specialist in Energy and Natural Resources Policy
Specialist in Transportation Policy
pfolger@crs.loc.gov, 7-1517
jfrittelli@crs.loc.gov, 7-7033
Kristina Alexander
Neelesh Nerurkar
Legislative Attorney
Specialist in Energy Policy
kalexander@crs.loc.gov, 7-8597
nnerurkar@crs.loc.gov, 7-2873
Harold F. Upton
Marc Humphries
Analyst in Natural Resources Policy
Analyst in Energy Policy
hupton@crs.loc.gov, 7-2264
mhumphries@crs.loc.gov, 7-7264
Henry B. Hogue
Francis X. McCarthy
Analyst in American National Government
Analyst in Emergency Management Policy
hhogue@crs.loc.gov, 7-0642
fmccarthy@crs.loc.gov, 7-9533
Adam Vann
Charles V. Stern
Legislative Attorney
Analyst in Natural Resources Policy
avann@crs.loc.gov, 7-6978
cstern@crs.loc.gov, 7-7786
Jon O. Shimabukuro
Legislative Attorney
jshimabukuro@crs.loc.gov, 7-7990
Congressional Research Service
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